FILED PURSUANT TO RULE 424(b)(3)
REGISTRATION NO. 333-104561
PROSPECTUS
(CITGO PETROLEUM CORPORATION)
$550,000,000
CITGO PETROLEUM CORPORATION
EXCHANGE OFFER FOR $550,000,000
11 3/8% SENIOR NOTES DUE 2011
---------------------
We are offering to exchange our 11 3/8% senior notes due 2011, or the
"exchange notes," for our currently outstanding 11 3/8% senior notes due 2011,
or the "outstanding notes." The exchange notes are substantially identical to
the outstanding notes, except that the exchange notes have been registered under
the federal securities laws, and will not bear any legend restricting their
transfer. The exchange notes will represent the same debt as the outstanding
notes, and we will issue the exchange notes under the same indenture.
The principal features of the exchange offer are as follows:
- The exchange offer expires at 5:00 p.m., New York City time, on
October 14, 2003, unless extended.
- We will exchange all outstanding notes that are validly tendered and
not validly withdrawn prior to the expiration of the exchange offer.
- You may withdraw tendered outstanding notes at any time prior to the
expiration of the exchange offer.
- We do not intend to apply for listing of the exchange notes on any
securities exchange or to arrange for them to be quoted on any
quotation system.
- The exchange offer is subject to customary conditions, including the
condition that the exchange offer not violate applicable law or any
applicable interpretation of the staff of the Securities and
Exchange Commission, or the "SEC."
- The exchange of outstanding notes for exchange notes pursuant to the
exchange offer will not be a taxable event for United States federal
income tax purposes.
- We will not receive any proceeds from the exchange offer.
Each broker-dealer that receives exchange notes for its own account
pursuant to the exchange offer must acknowledge that it will deliver a
prospectus in connection with any resale of such exchange notes. The letter of
transmittal states that, by so acknowledging and by delivering a prospectus, a
broker-dealer will not be deemed to admit that it is an "underwriter" within the
meaning of the Securities Act. This prospectus, as it may be amended or
supplemented from time to time, may be used by a broker-dealer in connection
with resales of exchange notes received in exchange for outstanding notes where
such outstanding notes were acquired by such broker-dealer as a result of
market-making activities or other trading activities. We have agreed that, for a
period of 180 days after the expiration date, as defined herein, we will make
this prospectus available to any broker-dealer for use in connection with any
such resale. See "Plan of Distribution."
---------------------
INVESTING IN THE EXCHANGE NOTES INVOLVES RISKS. SEE "RISK FACTORS"
BEGINNING ON PAGE 14.
---------------------
NEITHER THE U.S. SECURITIES AND EXCHANGE COMMISSION NOR ANY OTHER FEDERAL
OR STATE AGENCY HAS APPROVED OR DISAPPROVED OF THE SECURITIES TO BE DISTRIBUTED
IN THE EXCHANGE OFFER, NOR HAVE ANY OF THESE ORGANIZATIONS DETERMINED THAT THIS
PROSPECTUS IS TRUTHFUL OR COMPLETE. ANY REPRESENTATION TO THE CONTRARY IS A
CRIMINAL OFFENSE.
The date of this Prospectus is September 9, 2003.
You should rely only on the information contained in this prospectus. We
have not authorized anyone to provide you with different information. We are not
making an offer of these exchange notes in any state where the offer is not
permitted. You should not assume that the information contained in this
prospectus is accurate as of any date other than the date on the front cover of
this prospectus. Our business, financial condition, results of operations and
prospects may have changed since that date.
----------
TABLE OF CONTENTS
<Table>
<Caption>
PAGE
----
INDUSTRY AND MARKET DATA................................ 3
FORWARD LOOKING STATEMENTS.............................. 3
PROSPECTUS SUMMARY...................................... 4
RISK FACTORS............................................ 14
USE OF PROCEEDS......................................... 23
CAPITALIZATION.......................................... 23
SELECTED CONSOLIDATED FINANCIAL AND
OPERATING DATA........................................ 23
MANAGEMENT'S DISCUSSION AND
ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS................................. 26
BUSINESS................................................ 45
MANAGEMENT.............................................. 57
RELATED PARTY TRANSACTIONS.............................. 61
THE EXCHANGE OFFER...................................... 62
DESCRIPTION OF THE EXCHANGE NOTES....................... 69
SUMMARY OF U.S. FEDERAL INCOME TAX
CONSIDERATIONS........................................ 106
PLAN OF DISTRIBUTION.................................... 109
LEGAL MATTERS........................................... 109
EXPERTS................................................. 109
WHERE YOU CAN FIND MORE
INFORMATION........................................... 109
INDEX TO CONSOLIDATED FINANCIAL
STATEMENTS............................................ F-1
</Table>
----------
This exchange offer is not being made to, and we will not accept surrenders
for exchange from, holders of outstanding notes in any jurisdiction in which the
exchange offer or the acceptance thereof would not be in compliance with the
securities or blue sky laws of that jurisdiction.
2
INDUSTRY AND MARKET DATA
We obtained the market and competitive position data used throughout this
prospectus from our own research, surveys or studies conducted by third parties
and industry or general publications. Industry publications and surveys
generally state that they have obtained information from sources believed to be
reliable, but do not guarantee the accuracy and completeness of that
information. While we believe that each of these studies and publications is
reliable, we have not independently verified that data, and we do not make any
representations as to the accuracy of that information. Similarly, we believe
our internal research is reliable, but it has not been verified by any
independent sources.
FORWARD LOOKING STATEMENTS
Certain information included in this prospectus may be deemed to be
"forward-looking statements" within the meaning of Section 27A of the Securities
Act of 1933, as amended, or the "Securities Act," and Section 21E of the
Securities Exchange Act of 1934, as amended, or the "Exchange Act." All
statements, other than statements of historical facts, included in this
prospectus, are forward-looking statements. When used in this document, the
words "anticipate," "estimate," "expect," "project," "believe" and similar
expressions are intended to identify forward-looking statements.
These statements are based on assumptions and assessments made by our
management in light of their experience and their perception of historical
trends, current conditions, expected future developments and other factors they
believe to be appropriate. Any forward-looking statements are not guarantees of
our future performance and are subject to risks and uncertainties that could
cause actual results, developments and business decisions to differ materially
from those contemplated by these forward-looking statements. We disclaim any
duty to update any forward-looking statements. Some of the factors that may
cause actual results, developments and business decisions to differ materially
from those contemplated by these forward-looking statements include the risk
factors discussed under the heading "Risk Factors."
3
PROSPECTUS SUMMARY
The following summary highlights selected information contained in this
prospectus. You should read this summary together with the more detailed
information that is contained in this prospectus. Unless otherwise indicated or
the context requires otherwise, all references in this prospectus to "CITGO,"
"our company," "we," "us," "our," or similar references mean CITGO Petroleum
Corporation and its consolidated subsidiaries and references to "notes" means
the outstanding notes and the exchange notes.
THE EXCHANGE OFFER
For a more complete description of the terms of the exchange offer, see
"The Exchange Offer" below in this prospectus.
SECURITIES OFFERED.................. 550 million aggregate principal amount
of 11 3/8% senior notes due 2011.
EXCHANGE OFFER...................... We are offering to exchange $1,000
principal amount of our 11 3/8% senior
notes due February 1, 2011, which have
been registered under the Securities
Act, for each $1,000 principal amount
of our currently outstanding 11 3/8%
senior notes due February 1, 2011,
which were issued in a private offering
on February 27, 2003. You are entitled
to exchange your outstanding notes for
freely tradable exchange notes with
substantially identical terms to the
outstanding notes. The exchange offer
is intended to satisfy your
registration rights. After the exchange
offer is complete, you will no longer
be entitled to any exchange or
registration rights with respect to
your outstanding notes. Accordingly, if
you do not exchange your outstanding
notes, you will not be able to reoffer,
resell or otherwise dispose of your
outstanding notes unless you comply
with the registration and prospectus
delivery requirements of the Securities
Act, or there is an exemption
available.
We will accept any and all outstanding
notes validly tendered and not
withdrawn prior to 5:00 p.m., New York
City time, on October 14, 2003. Holders
may tender some or all of their
outstanding notes pursuant to the
exchange offer. However, notes may be
tendered only in integral multiples of
$1,000 in principal amount. The form
and terms of the exchange notes are
substantially identical to the form and
terms of the outstanding notes except
that:
o the exchange notes have been
registered under the federal
securities laws and will not bear
any legend restricting their
transfer;
o the exchange notes bear a
different CUSIP number than the
outstanding notes; and
o the holders of the exchange notes
will not be entitled to certain
rights under the registration
rights agreement, including the
provisions for an increase in the
interest rate on the outstanding
notes in some circumstances
relating to the timing of the
exchange offer.
See "The Exchange Offer."
TRANSFERABILITY OF EXCHANGE
NOTES............................... We believe you will be able to transfer
freely the exchange notes without
registration or any prospectus delivery
requirement so long as you are able to
make the representations listed under
"The Exchange Offer -- Purpose and
Effect of the Exchange Offer --
Transferability." If you are a
broker-dealer that acquired outstanding
notes as a result of market-making or
other trading activities, you must
deliver a prospectus in connection with
any resale of the exchange notes. See
"Plan of Distribution."
EXPIRATION DATE..................... The exchange offer will expire at 5:00
p.m., New York City time, on October
14, 2003, which time and date we call
the expiration date, unless we decide
to extend it.
CONDITIONS TO THE EXCHANGE
OFFER............................... The exchange offer is subject to
several customary conditions, which may
be waived by us. The exchange offer is
not conditioned upon any minimum
principal amount of outstanding notes
being tendered.
4
PROCEDURES FOR TENDERING
OUTSTANDING NOTES................... If you wish to accept the exchange
offer, you must complete, sign and date
the letter of transmittal, or a
facsimile of it, in accordance with the
instructions contained in this
prospectus and in the letter of
transmittal. You should then mail or
otherwise deliver the letter of
transmittal, or facsimile, together
with the outstanding notes to be
exchanged and any other required
documentation, to the exchange agent at
the address set forth in this
prospectus and in the letter of
transmittal to arrive by 5:00 p.m., New
York City time, on the expiration date.
By executing the letter of transmittal,
you will represent to us that, among
other things:
o you, or the person or entity
receiving the related exchange
notes, are acquiring the
exchange notes in the ordinary
course of business;
o neither you nor any person or
entity receiving the related
exchange notes is engaging in or
intends to engage in a
distribution of the exchange notes
within the meaning of the federal
securities laws;
o neither you nor any person or
entity receiving the related
exchange notes has an arrangement
or understanding with any person
or entity to participate in any
distribution of the exchange
notes;
o you are not affiliated with us;
and
o you are not acting on behalf of
any person or entity that could
not truthfully make these
statements.
See "The Exchange Offer -- Procedures
for Tendering Outstanding Notes" and
"Plan of Distribution."
SPECIAL PROCEDURES FOR BENEFICIAL
HOLDERS............................. If you are the beneficial holder of
outstanding notes that are registered
in the name of your broker, dealer,
commercial bank, trust company or other
nominee, and you wish to tender in the
exchange offer, you should contact the
person in whose name your outstanding
notes are registered promptly and
instruct that person to tender on your
behalf. See "The Exchange Offer --
Procedures for Tendering Outstanding
Notes."
GUARANTEED DELIVERY
PROCEDURES.......................... If you wish to tender your outstanding
notes and you cannot deliver those
outstanding notes, the letter of
transmittal or any other required
documents to the exchange agent before
the expiration date, you may tender
your outstanding notes according to the
guaranteed delivery procedures set
forth under "The Exchange
Offer--Guaranteed Delivery Procedures."
ACCEPTANCE OF OUTSTANDING
NOTES AND DELIVERY OF
EXCHANGE NOTES...................... Subject to certain conditions, we will
accept for exchange any and all
outstanding notes which are properly
tendered in the exchange offer before
5:00 p.m., New York City time, on the
expiration date. The exchange notes
will be delivered promptly after the
expiration date. See "The Exchange
Offer -- Exchange Date."
EFFECT OF NOT TENDERING............. Any outstanding notes that are not
tendered or that are tendered but not
accepted will remain subject to the
restrictions on transfer. Because the
outstanding notes have not been
registered under the federal securities
laws, they bear a legend restricting
their transfer absent registration or
the availability of a specific
exemption from registration. Upon the
completion of the exchange offer, we
will have no further obligations,
except under limited circumstances, to
provide for registration of the
outstanding notes under the federal
securities laws. See "The Exchange
Offer -- Consequences of Failure to
Exchange."
INTEREST ON THE EXCHANGE NOTES
AND THE OUTSTANDING NOTES........... The exchange notes will bear interest
from the most recent interest payment
date to which interest has been paid on
the outstanding notes or, if no
interest has been paid, from February
27, 2003. Interest on the outstanding
notes accepted for exchange will cease
to accrue upon the issuance of the
exchange notes.
5
WITHDRAWAL RIGHTS................... You may withdraw tenders at any time
prior to 5:00 p.m., New York City time,
on the expiration date pursuant to the
procedures described under "The
Exchange Offer -- Withdrawal Rights."
SUMMARY OF FEDERAL INCOME TAX
CONSEQUENCES........................ The exchange of outstanding notes for
exchange notes will not be a taxable
event for United States federal income
tax purposes. You will not recognize
any taxable gain or loss as a result of
exchanging outstanding notes for
exchange notes and you will have the
same tax basis and holding period in
the exchange notes as you had in the
outstanding notes immediately before
the exchange. See "Summary of U.S.
Federal Income Tax Considerations."
USE OF PROCEEDS..................... We will not receive any proceeds from
the issuance of exchange notes pursuant
to the exchange offer.
EXCHANGE AGENT...................... The Bank of New York is serving as
exchange agent in connection with the
exchange notes. The address, telephone
number and facsimile number of the
exchange agent is set forth under "The
Exchange Offer -- Exchange Agent."
6
THE EXCHANGE NOTES
The summary below describes the principal terms of the exchange notes. The
financial terms and covenants of the exchange notes are the same as the
outstanding notes. Some of the terms and conditions described below are subject
to important limitations and exceptions. The "Description of the Exchange Notes"
section of this prospectus contains a more detailed description of the terms and
conditions of the exchange notes.
ISSUER.............................. CITGO Petroleum Corporation
NOTES OFFERED....................... $550 million in aggregate principal
amount of 11 3/8% senior notes due
2011.
MATURITY DATE....................... February 1, 2011.
INTEREST PAYMENTS................... February 1 and August 1 of each year,
beginning February 1, 2004.
RANKING............................. The exchange notes will be our senior
unsecured obligations. They will rank
equal in right of payment with our
existing and future senior
indebtedness, including the outstanding
notes, and senior in right of payment
to any of our future subordinated
indebtedness. Because the exchange
notes are unsecured, secured debt and
other secured obligations will
effectively rank senior to the exchange
notes. The exchange notes will be
structurally subordinated to all
indebtedness and other liabilities of
our subsidiaries.
OPTIONAL REDEMPTION................. We may redeem some or all of the
exchange notes beginning on February 1,
2007 at the redemption prices listed
under "Description of the Exchange
Notes -- Optional Redemption."
At any time prior to February 1, 2006,
we may redeem at our option on one or
more occasions up to 35% of the sum of
the original aggregate principal amount
of the exchange notes and the original
aggregate principal amount of any other
notes issued under the same indenture,
including the outstanding notes, with
the net proceeds of certain equity
offerings or cash capital contributions
specified in "Description of the
Exchange Notes," at a redemption price
equal to 111.375% of their principal
amount plus accrued and unpaid interest
to the redemption date, so long as at
least 65% of the original aggregate
principal amount of the exchange notes
and such other notes remains
outstanding after the redemption and
each such redemption occurs within 60
days after the date of the related
equity offering or cash capital
contribution.
In addition, at any time prior to
February 1, 2007 we may redeem all, but
not less than all, of the notes at a
redemption price equal to 100% of their
principal amount plus the Applicable
Premium (as defined in "Description of
the Exchange Notes -- Optional
Redemption") as of, and accrued and
unpaid interest to, the redemption
date.
CHANGE OF CONTROL................... If we experience a Change of Control as
defined under "Description of the
Exchange Notes -- Change of Control,"
we will be required to make an offer to
repurchase the exchange notes at a
price equal to 101% of their principal
amount, plus accrued and unpaid
interest, if any, to the date of
repurchase.
RESTRICTIVE COVENANTS............... The terms of the exchange notes
restrict our ability and certain of our
subsidiaries' ability to, among other
things:
o incur additional indebtedness;
o pay dividends or make distributions
to our stockholder;
o repurchase or redeem capital stock;
o make investments or other
restricted payments;
o create liens or enter into
sale-leaseback transactions;
7
o enter into transactions with our
stockholder and affiliates;
o sell assets; and
o merge, consolidate or transfer
assets.
After an Investment Grade Rating Event,
as defined under "Description of the
Exchange Notes," has occurred, the
foregoing covenants will cease to be in
effect or will be modified. The terms
of the exchange notes will then
restrict our ability and certain of our
subsidiaries' ability to, among other
things:
o create liens or enter into
sale-leaseback transactions with
respect to specified assets; and
o merge, consolidate or transfer
assets.
The covenants both before and after an
Investment Grade Rating Event are
subject to a number of exceptions and
qualifications. See "Description of the
Exchange Notes -- Certain Covenants"
and "Description of the Exchange Notes
-- Certain Investment Grade Covenants."
CITGO PETROLEUM CORPORATION
We are a leading energy company engaged in the refining, marketing and
transportation of petroleum products including gasoline, diesel fuel, jet fuel,
petrochemicals, lubricants, asphalt and refined waxes. We operate fuels
refineries in Louisiana, Texas and Illinois and asphalt refineries in New Jersey
and Georgia. We are also a 41% participant in LYONDELL-CITGO Refining LP, or
"LYONDELL-CITGO," a joint venture fuels refinery located in Houston, Texas. Our
interests in these refineries result in a total crude oil capacity of
approximately 865,000 barrels per day. We are also one of the five largest
branded gasoline suppliers within the United States with more than 13,000
branded, independently owned and operated locations and an approximate 7% market
share. Our marketing activities are focused primarily within the continental
United States, east of the Rocky Mountains, with our refineries and supply
distribution networks well-located for the markets we serve. We employed over
4,300 employees and had total assets of approximately $7.0 billion at December
31, 2002. For the year ended December 31, 2002, we generated $19.4 billion of
net sales and $180 million of net income.
Our transportation fuel customers primarily include branded wholesale
independent marketers, major convenience store chains and airlines located
mainly east of the Rocky Mountains. We generally market our asphalt to
independent paving contractors on the East and Gulf Coasts and in the Midwest of
the United States. We sell lubricants principally in the United States to
independent marketers, mass marketers and industrial customers. We sell
lubricants, gasoline, and distillates in various Latin American markets. We sell
petrochemical feedstocks and industrial products to various manufacturers and
industrial companies throughout the United States. We sell petroleum coke
primarily in international markets.
We were incorporated in Delaware in 1983. We are a direct, wholly-owned
subsidiary of PDV America, Inc., or "PDV America," which itself is a
wholly-owned subsidiary of PDV Holding, Inc., or "PDV Holding." Our ultimate
parent is Petroleos de Venezuela, S.A., or "PDVSA," which term may also be used
herein to refer to one or more of its subsidiaries. PDVSA is the national oil
company of the Bolivarian Republic of Venezuela.
8
OUR CORPORATE STRUCTURE
(CHART)
For more information, you can contact us at One Warren Place, 6100 South
Yale Avenue, Tulsa, Oklahoma 74136, telephone (918) 495-4000, www.citgo.com.
RISK FACTORS
Investing in the exchange notes involves substantial risks. See "Risk
Factors" for a discussion of certain factors that should be considered by
prospective purchasers before participating in the exchange offer.
9
SUMMARY OF CONSOLIDATED FINANCIAL AND OPERATING DATA
The following summary financial data for the years ended and as of December
31, 2000, 2001 and 2002 are derived from our audited consolidated financial
statements, including the notes thereto, appearing elsewhere in this prospectus.
The following summary financial data for the years ended and as of December 31,
1998 and 1999 are derived from audited consolidated financial statements,
including the notes thereto, not included in this prospectus. The data for the
years ended and as of December 31, 1998, 1999, 2000 and 2001 have been restated
to give retroactive effect to the contribution by PDV America of the VPHI
Midwest, Inc. ("VPHI") common stock to us. The primary asset of VPHI is a fuels
refinery in Lemont, Illinois. This table should be read in conjunction with
"Management's Discussion and Analysis of Financial Condition and Results of
Operations" and our financial statements, including the notes thereto, appearing
elsewhere in this prospectus.
<Table>
<Caption>
YEAR ENDED DECEMBER 31, SIX MONTHS ENDED JUNE 30,
------------------------------------------------------------- ------------------------
1998 1999 2000 2001 2002 2003 2002
--------- --------- --------- --------- --------- ----------- ---------
(AS RESTATED)(1)
------------------------------------------------
(IN MILLIONS, EXCEPT AS NOTED)
STATEMENT OF INCOME DATA:
Net sales and sales to affiliates ...... $10,960.2 $13,334.4 $22,157.2 $19,601.2 $19,358.3 $12,396.7 $ 8,464.9
Equity in earnings of affiliates ....... 82.3 22.2 58.7 108.9 101.3 44.6 49.3
Other income (expense) (including
insurance recoveries) ................ (12.3) (29.0) (26.0) (5.2) 386.9 160.0 196.0
Cost of sales and operating expenses ... 10,305.6 12,804.2 21,370.3 18,734.7 19,211.3 12,017.0 8,395.8
Selling, general and administrative
expenses ............................. 254.3 239.1 226.6 292.1 284.9 137.3 151.3
Interest expense ....................... 101.0 94.6 85.6 69.2 67.4 55.9 33.2
Capital lease interest charge .......... 14.2 12.7 11.0 9.1 7.0 2.8 3.8
Minority interest ...................... 1.2 0.2 1.8 2.0 -- -- --
Income taxes ........................... 128.2 54.2 182.6 206.2 95.9 139.8 45.4
Cumulative effect of accounting
change ............................... -- -- -- 13.6 -- -- --
--------- --------- --------- --------- --------- --------- ---------
Net income (loss) ...................... $ 225.7 $ 122.6 $ 312.0 $ 405.2 $ 180.0 $ 248.5 $ 80.7
--------- --------- --------- --------- --------- --------- ---------
CASH FLOW DATA:
Operating activities ................... $ 671.1 $ 196.2 $ 803.3 $ 584.5 $ 818.3 $ 326.7 $ 121.7
Investing activities ................... (221.9) (249.0) (153.7) (292.8) (788.9) (224.7) (420.0)
Financing activities ................... (446.7) 116.7 (727.6) (206.3) (100.7) 111.3 212.8
--------- --------- --------- --------- --------- --------- ---------
Increase (decrease) during the
period ............................... $ 2.5 $ 63.9 $ (78.0) $ 85.4 $ (71.3) $ 213.3 $ (85.5)
--------- --------- --------- --------- --------- --------- ---------
SELECTED OPERATING DATA:(2)
Refining capacity (000's of barrels
per day) ............................. 637 637 644 644 644 644 644
Crude oil throughput (000's of
barrels per day) ..................... 588 592 620 569 543 624 520
Total throughput (000's of barrels
per day) ............................. 718 707 750 698 654 757 642
Utilization (%) ........................ 92% 93% 96% 88% 84% 97% 81%
Wholesale fuel sales (millions of
gallons) ............................. 13,029 13,143 13,441 13,566 13,758 7,036 6,833
</Table>
<Table>
BALANCE SHEET DATA (AT PERIOD END):
Current assets ......................... $ 1,570.8 $ 2,247.6 $ 2,597.8 $ 2,287.0 $ 2,187.5 $ 2,455.3 $ 2,353.4
Current liabilities .................... 1,198.6 1,578.3 2,147.0 1,530.8 1,999.1 1,632.3 2,156.4
--------- --------- --------- --------- --------- --------- ---------
Working capital ........................ $ 372.2 $ 669.3 $ 450.8 $ 756.2 $ 188.4 $ 823.0 $ 197.0
Net property, plant and equipment ...... 3,419.9 3,417.7 3,287.2 3,292.5 3,750.2 3,829.2 3,505.3
Total assets ........................... 6,028.1 6,642.0 6,805.7 6,509.1 6,986.9 7,308.6 6,893.8
Total debt ............................. 1,524.8 1,694.1 1,198.6 1,478.9 1,347.5 1,515.5 1,570.0
Total shareholder's equity ............. 2,222.2 2,385.1 2,476.2 2,401.3 2,559.2 2,809.0 2,482.2
OTHER FINANCIAL DATA:
Capital expenditures(3) ................ $ 230.2 $ 248.0 $ 122.0 $ 253.5 $ 711.8 $ 208.7 $ 350.0
Depreciation and amortization .......... 261.8 274.0 290.5 288.9 298.7 162.8 145.0
EBITDA(4) .............................. 730.9 558.1 881.7 978.6 649.0 609.8 308.1
Ratio of total debt to EBITDA(4) ....... 2.1x 3.0x 1.4x 1.5x 2.1x 2.5x 5.1x
Ratio of EBITDA to interest
expense(4) ........................... 6.3x 5.2x 9.1x 12.5x 8.7x 10.4x 8.3x
Total debt to book capitalization ...... 40.7% 41.5% 32.6% 38.1% 34.5% 35.0% 38.7%
Ratio of earnings to fixed
charges(5) ........................... 3.82x 2.89x 5.62x 7.08x 3.66x 5.15x 3.56x
</Table>
- ----------
(1) Amounts shown for the years ended December 31, 1998, 1999, 2000 and
2001 have been restated to give effect to the contribution to our
capital of the common stock of VPHI, which indirectly owns the Lemont,
Illinois refinery, as if it took place on January 1, 1998. The
combination actually occurred on January 1, 2002.
(2) Refining data for Lake Charles, Corpus Christi and Lemont refineries.
(3) 2002 capital expenditures include $220 million in spending to rebuild
the crude unit at our Lemont refinery due to a fire in 2001.
10
(4) EBITDA is defined as net income plus interest expense, income taxes,
depreciation and amortization. EBITDA is used as a measure of
performance by management and is not a measure of performance under
generally accepted accounting principles, or GAAP. While EBITDA should
not be considered as a substitute for net income, cash flows from
operating activities and other income or cash flow statement data
prepared in accordance with GAAP, or as a measure of profitability or
liquidity, we disclose it because management understands that EBITDA is
customarily used by certain investors as one measure of a company's
ability to service debt. Because EBITDA is not calculated identically
by all companies, our presentation may not be comparable to similarly
titled measures presented by other companies.
Shown below is a reconciliation between EBITDA for each of the years
presented in the table and our net income for those years, as reflected
earlier in the table and in our financial statements:
<Table>
<Caption>
YEAR ENDED DECEMBER 31, SIX MONTHS ENDED JUNE 30,
--------------------------------------------------------------- -------------------------
(IN MILLIONS) 1998 1999 2000 2001 2002 2003 2002
----------- ----------- ----------- ----------- ----------- ------------ -----------
EBITDA $ 730.9 $ 558.1 $ 881.7 $ 978.6 $ 649.0 $ 609.8 $ 308.1
less Interest expense 101.0 94.6 85.6 69.2 67.4 55.9 33.2
less Capital lease interest charge 14.2 12.7 11.0 9.1 7.0 2.8 3.8
less Income taxes 128.2 54.2 182.6 206.2 95.9 139.8 45.4
less Depreciation and amortization 261.8 274.0 290.5 288.9 298.7 162.8 145.0
----------- ----------- ----------- ----------- ----------- ----------- -----------
Net income $ 225.7 $ 122.6 $ 312.0 $ 405.2 $ 180.0 $ 248.5 $ 80.7
=========== =========== =========== =========== =========== =========== ===========
</Table>
EBITDA for the year ended December 31, 2002 includes the effect of $314
million of business interruption insurance recoveries and $78 million
of property damage insurance recoveries that exceeded the net book
value of the property destroyed and related expenses. These insurance
recoveries were related to a fire occurring at our Lemont refinery in
August 2001 and the resulting shutdown of such refinery until May of
2002 for cleanup and rebuild.
(5) For the purposes of calculating the ratio of earnings to fixed charges,
"earnings" consist of income before income taxes and cumulative effect
of accounting changes plus fixed charges (excluding capitalized
interest), amortization of previously capitalized interest and certain
adjustments to equity in income of affiliates. "Fixed charges" include
interest expense, capitalized interest, amortization of debt issuance
costs and a portion of operating lease rent expense deemed to be
representative of interest.
11
QUARTERLY RESULTS OF OPERATIONS
The following is a summary of the quarterly results of operations for the
six months ended June 30, 2003 and the years ended December 31, 2002 and 2001:
<Table>
<Caption>
1ST QTR. 2ND QTR.
(000S OMITTED) (000S OMITTED)
2003
Sales $ 6,375,681 $ 6,021,068
=============== ===============
Cost of sales and
operating expenses $ 6,205,790 $ 5,811,233
=============== ===============
Gross margin $ 169,891 $ 209,835
=============== ===============
Net income $ 139,811 $ 108,709
=============== ===============
</Table>
<Table>
<Caption>
1ST QTR. 2ND QTR. 3RD QTR. 4TH QTR.
(000S OMITTED)
2002
Sales $ 3,671,422 $ 4,793,441 $ 5,410,571 $ 5,482,888
=========== =========== =========== ===========
Cost of sales and operating
expenses $ 3,708,903 $ 4,686,882 $ 5,298,606 $ 5,516,925
=========== =========== =========== ===========
Gross margin $ (37,481) $ 106,559 $ 111,965 $ (34,037)
=========== =========== =========== ===========
Net (loss) income $ (15,581) $ 96,284 $ 56,920 $ 42,389
=========== =========== =========== ===========
</Table>
12
<Table>
<Caption>
1ST QTR. 2ND QTR. 3RD QTR. 4TH QTR.
(000S OMITTED)
2001
Sales, as previously reported $ 4,960,424 $ 5,748,203 $ 5,179,450 $ 3,733,169
Effect of contribution of VPHI (1)
1,127 7,768 (11,338) (17,635)
----------- ----------- ----------- -----------
Sales, as restated $ 4,961,551 $ 5,755,971 $ 5,168,112 $ 3,715,534
=========== =========== =========== ===========
Cost of sales and operating
expenses, as previously reported $ 4,812,363 $ 5,462,848 $ 4,988,825 $ 3,648,555
Effect of contribution of VPHI (1)
(64,895) (162,081) (9,067) 58,104
----------- ----------- ----------- -----------
Cost of sales and operating
expenses, as restated $ 4,747,468 $ 5,300,767 $ 4,979,758 $ 3,706,659
=========== =========== =========== ===========
Gross margin, as previously reported $ 148,061 $ 285,355 $ 190,625 $ 84,614
Effect of contribution of VPHI (1)
66,022 169,849 (2,271) (75,739)
----------- ----------- ----------- -----------
Gross margin, as restated $ 214,083 $ 455,204 $ 188,354 $ 8,875
=========== =========== =========== ===========
Income before cumulative effect
of change in accounting
principle, as previously reported $ 66,350 $ 149,571 $ 87,925 $ 178
Effect of contribution of VPHI (1)
32,230 101,718 (15,759) (30,629)
----------- ----------- ----------- -----------
Income before cumulative effect
of change in accounting
principle, as restated $ 98,580 $ 251,289 $ 72,166 $ (30,451)
=========== =========== =========== ===========
Net income, as previously reported $ 79,350 $ 149,571 $ 87,925 $ 178
Effect of contribution of VPHI (1)
32,830 101,718 (15,759) (30,629)
----------- ----------- ----------- -----------
Net income (loss), as restated $ 112,180 $ 251,289 $ 72,166 $ (30,451)
=========== =========== =========== ===========
</Table>
(1) On January 1, 2002, PDV America, our parent company, made a contribution to
our capital of all of the common stock of PDV America's wholly owned subsidiary,
VPHI. No additional shares of our capital stock were issued in connection with
the contribution. Effective January 1, 2002, the accounts of VPHI were included
in our consolidated financial statements at the historical carrying value of PDV
America's investment in VPHI. We recorded the effects of this transaction in a
manner similar to pooling-of-interests accounting; accordingly, the quarterly
results of operations have been restated to present our results of operations
for the year ended December 31, 2001 as if the transaction had occurred on
January 1, 2001. The restated results of operations do not purport to be
indicative of the results of operations that actually would have resulted had
the combination occurred on January 1, 2001, or of future results of operations
of the combined entities. See Note 17 of our consolidated financial statements,
which are attached as an appendix to this prospectus.
13
RISK FACTORS
An investment in the exchange notes is subject to various risks, including
the risks discussed below. These risks should be considered carefully with the
information provided elsewhere in this prospectus before participating in the
exchange offer.
RISKS RELATED TO THE EXCHANGE OFFER
THERE HAS BEEN NO PRIOR MARKET FOR THE EXCHANGE NOTES AND THEREFORE YOUR ABILITY
TO SELL THE EXCHANGE NOTES MAY BE LIMITED.
Following the completion of this exchange offer, the exchange notes will be
freely tradable by most holders. See "The Exchange Offer." We do not intend to
list the exchange notes on any United States or foreign securities exchange. We
can give no assurances concerning the liquidity of any market that may develop
for the exchange notes, the ability of any investor to sell the exchange notes,
or the price at which investors would be able to sell their exchange notes. If a
market for the exchange notes does not develop, investors may be unable to
resell the exchange notes for an extended period of time, if at all.
Consequently, investors may not be able to liquidate their investment readily,
and lenders may not readily accept the exchange notes as collateral for loans.
We also cannot assure you that you will be able to sell your exchange notes
at a particular time or that the prices that you receive when you sell will be
favorable. We also cannot assure you as to the level of liquidity of the trading
market for the exchange notes or, in the case of any holders of outstanding
notes that do not exchange them, the trading market for those notes following
the offer to exchange those notes for exchange notes. Future trading prices of
the outstanding notes and exchange notes will depend on many factors, including:
o our operating performance and financial condition;
o our ability to complete the offer to exchange the outstanding notes for the
exchange notes;
o the interest of securities dealers in making a market for the outstanding
notes and the exchange notes; and
o the market for similar securities.
Historically, the market for non-investment grade debt has been subject to
disruptions that have caused volatility in the prices of these securities. There
can be no assurance that the market for the outstanding notes or the exchange
notes will not be subject to similar disruptions. Any disruptions may have a
negative effect on the holders of the notes, regardless of our prospects and
financial performance.
FAILURE TO EXCHANGE YOUR OUTSTANDING NOTES WILL LEAVE THEM SUBJECT TO TRANSFER
RESTRICTIONS.
Any outstanding notes that remain outstanding after this exchange offer
will continue to be subject to restrictions on their transfer. After this
exchange offer, holders of outstanding notes will not have any further rights
under the registration rights agreement, with limited exceptions. In general,
outstanding notes may not be offered or sold unless registered under the
Securities Act, except pursuant to an exemption from, or in a transaction not
subject to, the Securities Act and applicable state securities laws. We
currently do not anticipate registering the outstanding notes under the
Securities Act. As outstanding notes are tendered and accepted in the exchange
offer, the aggregate principal amount of outstanding notes will decrease, which
decrease will decrease their liquidity. Any market for outstanding notes that
are not exchanged could be adversely affected by the conclusion of this exchange
offer.
LATE DELIVERIES OF THE OUTSTANDING NOTES AND OTHER REQUIRED DOCUMENTS COULD
PREVENT A HOLDER FROM EXCHANGING ITS NOTES.
Holders are responsible for complying with all exchange offer procedures.
Issuance of exchange notes in exchange for outstanding notes will only occur
upon completion of the procedures described in this prospectus under the heading
"The Exchange Offer -- Procedures for Tendering Outstanding Notes." Therefore,
holders of outstanding notes who wish to exchange them for exchange notes should
allow sufficient time for completion of the exchange procedures. We are not
obligated to notify you of any failure to follow the proper procedures.
IF YOU ARE A BROKER-DEALER, YOUR ABILITY TO TRANSFER THE NOTES MAY BE
RESTRICTED.
A broker-dealer that purchased outstanding notes for its own account as
part of market-making or trading activities must deliver a prospectus when it
sells the exchange notes. Our obligation to make this prospectus available to
broker-dealers is limited. Consequently, we cannot guarantee that a proper
prospectus will be available to broker-dealers wishing to resell their exchange
notes.
14
RISKS RELATED TO OUR RELATIONSHIP WITH PDVSA
THE VENEZUELAN ECONOMIC AND POLITICAL ENVIRONMENT DISRUPTED OUR CRUDE OIL SUPPLY
LAST YEAR.
A nation-wide work stoppage by opponents of the government of Venezuela
began on December 2, 2002, and disrupted most activity in that country,
including the operations of PDVSA. A large portion of PDVSA's employees
abandoned their jobs during the month of December. PDVSA informed us that these
actions led to an employee termination process and an organizational
restructuring of PDVSA. PDVSA also informed us that its production of crude and
gas, as well as the export of crude oil and products, were severely affected by
these events in December.
As a result, in December 2002 we had to replace a portion of the crude oil
we would normally have purchased under our PDVSA supply contracts with purchases
of crude oil on the spot market on pricing and credit terms that are less
favorable than we would have obtained under the supply contracts. The price
terms of our supply contracts with PDVSA are designed to provide a measure of
stability to our refining margins. When we are required to purchase crude oil on
the spot market instead of under our contracts we lose this protection. In
addition, spot market trading companies require us to pay for delivered crude
oil on 10-day or prompt-pay terms instead of the 30-day terms under which we
would pay PDVSA pursuant to the supply contracts. Since January 2003, crude
supplies have been stabilized and we do not believe we will experience this
situation again. However, if we experience disruption to our purchases of crude
oil under the PDVSA supply agreements, we could experience additional volatility
in our earnings and cash flow.
THE VENEZUELAN WORK STOPPAGE PUT PRESSURE ON OUR LIQUIDITY.
The existence of the work stoppage and our ownership by PDVSA gave rise to
concerns about our financial condition. Because of the uncertainty in Venezuela,
all three major rating agencies reduced our debt ratings. The reactions that
followed increased the pressure on our liquidity. We were able to establish new
sources of liquidity that allowed us to meet all of our financial obligations.
See "Management's Discussion and Analysis of Financial Condition and Results of
Operations -- Liquidity and Capital Resources."
WE MAY NOT BE ABLE TO ACCESS NEW SOURCES OF LIQUIDITY.
In 2003, we repurchased approximately $90 million of taxable bonds and $138
million of tax-exempt bonds that had been issued through governmental entities
for our benefit. These repurchases were made because providers of letters of
credit supporting those bonds did not renew those letters of credit. We also
have an additional $20 million of letters of credit outstanding that back or
support other tax-exempt bonds that we have issued through governmental
entities, which are subject to renewal during 2003. We cannot provide any
assurances that those letters of credit will be renewed. We may not be able to
obtain replacement letters of credit to support those bonds and may need to
repurchase those bonds. We may not be able to reissue those bonds or replace
them in the absence of letter of credit support.
The inability to access these sources of liquidity may adversely affect our
financial condition.
WE MAY NOT BE ABLE TO IMPLEMENT SUCCESSFULLY OUR DISCRETIONARY CAPITAL
EXPENDITURE PROJECTS.
Because of the liquidity risks described above, we have taken steps to
reduce our planned discretionary capital expenditures in 2003 by approximately
$250 million and are continuing to review the timing and amount of scheduled
expenditures under our planned capital spending programs, including regulatory
and environmental projects in the near term. Because of this reduction, we may
be unable to undertake discretionary capital expenditure projects designed to
increase the productivity and profitability of our refineries. Other factors
beyond our control also may prevent or hinder our undertaking of some or all of
these projects, including compliance with or liability under environmental
regulations, a downturn in refining margins, technical or mechanical problems,
lack of availability of capital and other factors. Failure to successfully
implement these projects may adversely affect our business prospects and
competitive position in the industry.
WE RELY HEAVILY UPON SUPPLY CONTRACTS WITH OUR ULTIMATE PARENT THAT COULD BE
MODIFIED OR TERMINATED.
We have historically purchased a significant portion of our crude oil
requirements from PDVSA, our parent corporation, under supply agreements that
expire in 2006 through 2013 that we believe contain favorable terms that could
not be replicated with other suppliers. PDVSA supplied under the supply
agreements approximately 50% of the crude oil we refined in 2002.
PDVSA could cause the termination of the supply agreements or a
modification of the terms of the supply agreements for any number of reasons.
Certain covenants in our other debt instruments restrict, for so long as that
debt is outstanding, our ability to terminate or modify the supply agreements.
However, those covenants do not prevent PDVSA from taking actions to cause a
termination or modification of those agreements. By their terms, the supply
agreements give either party a right to terminate the agreements upon six months
notice if PDVSA no longer retains an ownership interest in us as indicated in
the agreements. Although
15
we expect that the supply agreements will be replaced as they expire, we cannot
assure you that we will be able to replace them and, if replaced, we are not
able to predict the terms of any replacement supply agreements, including
provisions for pricing crude oil.
The supply agreements permit PDVSA to decrease or stop providing us crude
oil based on the existence of force majeure. In the past, when the Venezuelan
Government ordered PDVSA to curtail the production of oil in response to a
decision by the Organization of the Petroleum Exporting Countries, otherwise
known as "OPEC," to reduce production, PDVSA invoked force majeure under the
supply agreements. PDVSA has invoked these force majeure provisions on several
occasions over the past few years.
If the supply agreements are modified or terminated or this source of crude
oil is interrupted due to any reason, we might not be able to find other sources
of heavy crude oil for our refineries on terms comparable to those contained in
the current supply agreements. As a result we could experience greater
volatility in our operating results than we historically have experienced.
PRICING PROVISIONS OF OUR SUPPLY AGREEMENTS WITH PDVSA MAY AFFECT OUR EARNINGS.
Our crude oil supply agreements with PDVSA are designed to provide a
measure of stability to our refining margins on crude oil supplied by PDVSA. The
supply agreements incorporate formula prices based on the market value of a
slate of refined products deemed to be produced from each particular grade of
crude oil or feedstock, less:
o specified deemed refining costs;
o specified actual costs, including transportation charges, natural gas and
electricity and import duties and taxes; and
o a deemed margin, which varies according to the grade of crude oil or
feedstock delivered.
Deemed margins and deemed costs are adjusted periodically by a formula
primarily based on the rate of inflation. Because deemed operating costs and the
slate of refined products deemed to be produced for a given barrel of crude oil
or other feedstock do not necessarily reflect the actual costs and yields in any
period, the actual refining margin we earn under the various supply agreements
will vary depending on, among other things, the efficiency with which we conduct
our operations during that period. Although we believe that these supply
agreements reduce the volatility of our earnings and cash flows, these supply
agreements also limit our ability to enjoy higher margins during periods when
the market price of crude oil is low relative to the then current market prices
for refined products.
WE ARE INDIRECTLY OWNED BY PDVSA, WHICH IS WHOLLY-OWNED BY THE BOLIVARIAN
REPUBLIC OF VENEZUELA.
PDVSA is a Venezuelan corporation 100% owned by the Bolivarian Republic of
Venezuela and controlled by the Venezuelan Government. PDVSA owns, indirectly,
100% of our capital stock. The Venezuelan Government is heavily dependent on
taxes, royalties and dividends from PDVSA and its affiliates to finance its
expenditures. The members of the board of directors of PDVSA are appointed by
the President of Venezuela. Any major corporate action of PDVSA may be subject
to the approval of the Venezuelan Government, as its sole shareholder. However,
the Bolivarian Republic of Venezuela is not legally liable for the obligations
of PDVSA or the obligations of its subsidiaries. We cannot assure you that PDVSA
or the Bolivarian Republic of Venezuela will not exercise their indirect control
of us in a manner detrimental to your interests.
PDVSA replaced four of our board members in January 2003, two of our board
members in May 2003 and three of our board members in August 2003 with new
directors, although one had previously served on our board. PDVSA also named
Luis E. Marin to succeed Oswaldo Contreras Maza as our President and Chief
Executive Officer as of August 1, 2003. So long as PDVSA retains a majority of
our voting stock, PDVSA's exercise of its power to replace some or all of our
directors, or to appoint additional directors to our board, will not constitute
a "Change of Control" under the indenture governing the notes.
While PDVSA has been operated since its formation as an independent
commercial entity, no assurance can be given that the Venezuelan Government's
policy as PDVSA's sole shareholder will not change in the future or that the
Venezuelan Government will not make decisions that could impact the commercial
affairs or management of PDVSA. In addition, no assurance can be given that the
Venezuelan Government will not make decisions that could impact our commercial
affairs in a manner adversely effecting our ability to perform our obligations,
including our obligations to you under the exchange notes and the indenture
governing the exchange notes. The Venezuelan operations of PDVSA and its
subsidiaries are subject to close regulation and supervision by various levels
and agencies of the Venezuelan Government, and there can be no assurance that
the current legal or regulatory framework will not be revised.
16
OUR PRIMARY SUPPLY OF CRUDE OIL COULD BE CONTROLLED BY THE GOVERNMENT OF
VENEZUELA.
Historically, members of OPEC have entered into agreements to regulate
their production of crude oil. The Bolivarian Republic of Venezuela is a member
of OPEC. PDVSA does not control the Venezuelan Government's international
affairs and the Government could enter into an agreement with OPEC or other oil
exporting countries that when implemented could require PDVSA to reduce its
crude oil production and export activities. Such a curtailment could be an event
of force majeure under our crude oil supply agreements, giving PDVSA the right
to reduce crude oil deliveries under those supply agreements for so long as such
curtailment is in effect. We are unable to predict if curtailments will be
imposed.
RECOURSE AGAINST OUR DIRECTORS FOR SECURITIES LAWS CLAIMS MAY BE LIMITED.
Certain members of our board of directors are residents of Venezuela, and
all or a substantial portion of the assets of those directors are located
outside the U.S. As a result, it may be difficult for investors to effect
service of process within the U.S. upon those directors or to enforce, in U.S.
courts, judgments obtained in such courts and predicated upon the civil
liability provisions of the U.S. federal securities laws. In addition, PDVSA may
replace members of our board of directors at any time, as it recently did in
January 2003, May 2003 and August 2003. This could make it even more difficult
to effect service of process on our directors. We have been advised that
liabilities predicated solely upon the civil liability provisions of the U.S.
federal securities laws in actions brought in Venezuela, in original actions or
in actions for enforcement of judgments of U.S. courts, may not be enforceable
in Venezuela.
RISKS RELATED TO THE EXCHANGE NOTES AND OTHER INDEBTEDNESS
WE AND OUR SUBSIDIARIES HAVE A SUBSTANTIAL AMOUNT OF INDEBTEDNESS OUTSTANDING
AND MAY INCUR SUBSTANTIALLY MORE DEBT, WHICH COULD ADVERSELY AFFECT OUR
FINANCIAL HEALTH AND PREVENT US FROM FULFILLING OUR OBLIGATIONS UNDER THE
EXCHANGE NOTES.
As of June 30, 2003, our total indebtedness was $1,515.5 million. In
addition, we and our subsidiaries may incur substantial additional indebtedness
in the future. Although the indenture governing the notes, as well as the
agreements relating to our existing credit facilities, contain restrictions on
the incurrence of additional indebtedness, these restrictions are subject to a
number of significant qualifications and exceptions, which would allow us to
incur a substantial amount of additional indebtedness. Our substantial
indebtedness could:
o require us to dedicate a substantial portion of our cash flow from
operations to payments in respect of our indebtedness, thereby reducing the
availability of our cash flow to fund working capital, capital
expenditures, potential acquisition opportunities and other general
corporate purposes;
o increase the amount of interest expense that we have to pay, because some
of our borrowings are at variable rates of interest, which, if interest
rates increase, will result in higher interest expense;
o increase our vulnerability to adverse general economic or industry
conditions;
o limit our flexibility in planning for, or reacting to, changes in our
business or the industry in which we operate;
o limit our ability to borrow additional funds;
o restrict us from making strategic acquisitions, introducing new
technologies or exploiting business opportunities;
o make it more difficult for us to satisfy our obligations with respect to
the exchange notes; and
o place us at a competitive disadvantage compared to our competitors that
have less debt.
Any additional indebtedness we incur will exacerbate the risks described
above. Also, the restrictions contained in the indenture governing the notes do
not prevent us from incurring obligations unless those obligations constitute
Indebtedness as defined in the indenture.
OUR SUBSIDIARIES ARE NOT GUARANTEEING THE EXCHANGE NOTES, WHICH ARE STRUCTURALLY
SUBORDINATED TO THE CLAIMS OF CREDITORS OF OUR SUBSIDIARIES.
We conduct a portion of our operations through subsidiaries and joint
ventures with other companies. Accordingly, we rely in part on dividends from
our subsidiaries and joint ventures, as well as payment of principal and
interest on advances made to our affiliates,
17
to provide funds necessary to meet our obligations, including the payment of
principal and interest on the notes. The ability of any subsidiary or joint
venture to pay dividends or make cash distributions to us is subject to
applicable laws, contractual restrictions and applicable joint venture rights
and obligations. None of our subsidiaries is an obligor or guarantor in respect
of the exchange notes. At June 30, 2003, our subsidiaries (excluding
intercompany liabilities) had approximately $1,035 million of liabilities
outstanding, including trade payables. They may also incur significant
liabilities in the future which would structurally be senior to the exchange
notes.
In addition, one of our significant assets is a joint venture interest in a
Houston refinery. This joint venture, LYONDELL-CITGO Refining LP, is not a
subsidiary of ours and will not be subject to the restrictions imposed on our
restricted subsidiaries by the indenture governing the notes.
In the event of any liquidation, dissolution, reorganization, bankruptcy or
other similar proceeding regarding our or our subsidiaries' assets, whether
voluntary or involuntary, the holders of our and our subsidiaries' secured debt
will be entitled to receive payment before we can make any payment with respect
to the exchange notes. In addition, our rights and our creditors' rights and the
rights of holders of the notes to realize upon the assets of any of our
subsidiaries would rank behind the claims of creditors (including trade
creditors and tort claimants) of those subsidiaries, except to the extent that
we may be a creditor with recognized claims against that subsidiary and any
preferred shareholders of that subsidiary. If any of the foregoing events
occurs, we cannot assure that we will have sufficient assets to pay amounts due
on our and our subsidiaries' debt and the notes. As a result, you may receive
less than you are entitled to receive or recover nothing if any liquidation,
dissolution, reorganizations, bankruptcy or other similar proceeding occurs.
WE WILL BE SUBSTANTIALLY RESTRICTED BY THE TERMS OF THE NOTES AND OUR OTHER
DEBT, WHICH COULD ADVERSELY AFFECT US AND INCREASE YOUR CREDIT RISK.
The indenture governing the notes and our credit agreements contain various
covenants and restrictions that limit our ability and certain of our
subsidiaries' ability to, among other things:
o incur additional indebtedness;
o pay dividends or make distributions to our stockholder;
o repurchase or redeem capital stock;
o make investments or other restricted payments;
o create liens and enter into sale-leaseback transactions;
o enter into transactions with our stockholder and affiliates;
o sell assets; and
o merge, consolidate or transfer assets.
In addition, our credit agreements contain covenants that require us to
maintain specified financial ratios and satisfy financial tests. As a result of
these covenants and restrictions, we are limited in how we conduct our business,
and we may be unable to raise additional debt or equity financing, to compete
effectively or to take advantage of new business opportunities.
We cannot assure you that we will be able to remain in compliance with
these covenants in the future and, if we fail to do so, that we will be able to
obtain waivers from the lenders and/or amend the covenants as we have in the
past.
OUR FAILURE TO COMPLY WITH RESTRICTIVE COVENANTS UNDER THE INDENTURE, OUR CREDIT
AGREEMENT AND OUR REVOLVING CREDIT FACILITIES COULD TRIGGER PREPAYMENT
OBLIGATIONS.
Our failure to comply with the restrictive covenants described above as
well as others in our credit facilities could result in an event of default,
which, if not cured or waived, could result in us being required to repay these
borrowings before their due date. If we are forced to refinance these borrowings
on less favorable terms, our results of operations and financial condition could
be adversely affected by increased costs and rates.
18
WE MAY NOT BE ABLE TO FULFILL OUR OBLIGATION TO PURCHASE THE NOTES UPON A CHANGE
OF CONTROL AND THIS OBLIGATION MAY DISCOURAGE A SALE OR TAKEOVER OF US.
Upon the occurrence of a Change of Control, as defined under "Description
of the Exchange Notes," we will be required to offer to repurchase the notes at
a purchase price equal to 101% of the outstanding principal amount thereof,
together with accrued and unpaid interest. A change of control is also a default
under our credit agreements. These change of control features may make a sale or
takeover more difficult for us. There can be no assurance that we would have
sufficient assets or be able to obtain sufficient third party financing on
favorable terms to satisfy all our obligations upon a change of control. If an
offer to repurchase the notes is required to be made and we do not have
available sufficient funds to pay for the notes or such a payment were to
constitute an event of default under our then existing credit or other
agreements, an event of default would occur under the indenture. The occurrence
of an event of default could result in acceleration of the maturity of the
notes. See "Description of the Exchange Notes." Furthermore, these provisions
would not necessarily afford protection to holders of the notes in the event of
a highly leveraged transaction that does not result in a Change of Control.
See "Description of the Exchange Notes -- Change of Control."
THE NOTES ARE NOT SECURED.
The notes are not secured by any of our assets or those of our
subsidiaries. Our secured credit facility is secured by our interest in CITGO
Pipeline Holding I, LLC, which owns shares of Colonial Pipeline Company and
membership interests in Colonial Ventures, LLC and CITGO Pipeline Holding II,
LLC, which owns shares of Explorer Pipeline Company. We will also be able to
incur additional secured debt to the extent permitted by the indenture governing
the notes. If we become insolvent or liquidated, or if payment under any of our
secured senior indebtedness is accelerated, the holders of that secured senior
indebtedness will be entitled to exercise the remedies available to a secured
lender under applicable law, in addition to any remedies that may be available
under documents pertaining to that secured senior indebtedness. To the extent
that the value of the collateral securing any of our senior indebtedness is
equal to or exceeds the amount of that senior indebtedness, holders of the notes
will be effectively subordinated to the claims of the holders of that senior
indebtedness.
RISKS RELATED TO OUR BUSINESS AND THE PETROLEUM INDUSTRY
VOLATILE MARGINS IN THE REFINING INDUSTRY MAY NEGATIVELY AFFECT OUR FUTURE
OPERATING RESULTS AND DECREASE OUR CASH FLOW.
Our financial results are primarily affected by the relationship, or
margin, between refined product prices and the prices for crude oil and other
feedstocks. The cost to acquire our feedstocks and the price at which we can
ultimately sell refined products depend on a variety of factors beyond our
control. Historically, refining margins have been volatile and they are likely
to continue to be volatile in the future. Although an increase or decrease in
prices for crude oil, feedstocks and blending components generally will result
in a corresponding increase or decrease in prices for refined products, there is
generally a lag in the realization of the corresponding increase or decrease in
prices for refined products.
Our supply agreements with PDVSA are designed to provide a measure of
stability to our refining margins through the pricing formula employed under
those contracts. If we are unable to continue to rely on these supply
agreements, our exposure to volatility would increase. Future volatility may
negatively affect our results of operations, since the margin between refined
products prices and feedstock prices may decrease below the amount needed for us
to generate net cash flow sufficient to meet our needs.
Specific factors that may affect our refining margins include:
o disruptions in our crude oil supply under our supply agreements with PDVSA;
o accidents, interruptions in transportation, inclement weather, the impact
of energy conservation efforts, or other events that cause unscheduled
shutdowns or otherwise adversely affect our plants, machinery, pipelines or
equipment, or those of our suppliers or customers;
o changes in the cost or availability to us of transportation for crude oil,
feedstocks and refined products;
o failure to successfully implement our planned capital projects or to
realize the benefits expected for those projects;
o changes in fuel specifications required by environmental and other laws,
particularly with respect to oxygenates and sulfur content;
o rulings, judgments or settlements in litigation or other legal matters,
including unexpected environmental remediation or compliance costs at our
facilities in excess of any reserves, and claims of product liability or
personal injury; and
19
o aggregate refinery capacity in our industry to convert heavy sour crude oil
into refined products.
Other factors that may affect our margins, as well as the margins in our
industry in general, include, in no particular order:
o domestic and worldwide refinery overcapacity or undercapacity;
o aggregate demand for crude oil and refined products, which is influenced by
factors such as weather patterns, including seasonal fluctuations, and
demand for specific products such as jet fuel, which may themselves be
influenced by acts of God, nature, war and acts of terrorism;
o domestic and foreign supplies of crude oil and other feedstocks and
domestic supply of refined products, including from imports;
o the ability of the members of OPEC to maintain oil price and production
controls;
o political conditions in oil producing regions, including the Middle East,
Africa and Latin America;
o refining industry utilization rates;
o pricing and other actions taken by competitors that impact the market;
o price, availability and acceptance of alternative fuels;
o adoption of or modifications to federal, state or foreign environmental,
taxation and other laws and regulations;
o price fluctuations in natural gas; and
o general economic conditions.
A SIGNIFICANT INTERRUPTION OR CASUALTY LOSS AT ONE OF OUR REFINERIES COULD
REDUCE OUR PRODUCTION, PARTICULARLY IF NOT FULLY COVERED BY OUR INSURANCE.
Our business includes owning and operating refineries. As a result, our
operations could be subject to significant interruption if one of our refineries
were to experience a major accident, be damaged by severe weather or other
natural disaster, or otherwise be forced to shut down. Any such shutdown would
reduce the production from the refinery. For example, on August 14, 2001, a fire
occurred at the crude oil distillation unit of the Lemont refinery. The crude
unit was destroyed and the refinery's other processing units were temporarily
taken out of production. A new crude unit did not become operational until May
2002. We have also experienced other accidents at our facilities that have
required us to shut down operations for significant periods of time. We also
face risks of mechanical failure and equipment shutdowns. In any of these
situations, undamaged refinery processing units may be dependent on or interact
with damaged sections of our refineries and, accordingly, are also subject to
being shut down. In the event any of our refining facilities is forced to shut
down for a significant period of time, it would have a material adverse effect
on our earnings, our other results of operations and our financial condition as
a whole.
OUR INSURANCE COVERAGE MAY BE INADEQUATE TO COVER ALL LOSSES.
We maintain insurance in accordance with industry standards with respect to
our assets and operations. However, not all operating risks are insurable, and
there can be no assurance that the insurance will be available in the future or
that insurance will cover all unanticipated losses in the event of a loss. As a
result of factors affecting the insurance market, insurance premiums with
respect to renewed insurance policies may increase significantly compared to
what we are currently paying. In addition, the level of coverage provided by
renewed policies may decrease, while deductibles and/or waiting periods may
increase, compared to our existing insurance policies.
ENVIRONMENTAL STATUTES AND REGULATIONS IMPOSE SIGNIFICANT COSTS AND LIABILITIES.
Our operations are subject to extensive federal and state environmental,
health and safety laws and regulations, including those governing discharges to
the air and water, the handling and disposal of solid and hazardous wastes and
the remediation of contamination. The failure to comply with those laws and
regulations can lead, among other things, to civil and criminal penalties and,
in some circumstances, the temporary or permanent curtailment or shutdown of all
or part of our operations in one or more of our refineries. The nature of our
refining business exposes us to risks of liability due to the production,
processing and refining, storage, transportation, and disposal of materials that
can cause contamination or personal injury if released into the environment.
20
Consistent with the experience of all U.S. refineries, environmental laws
and regulations have raised operating costs and necessitated significant capital
investments at our refineries. We believe that existing physical facilities at
our refineries are substantially adequate to maintain compliance with existing
applicable laws and regulatory requirements, other than:
o upgrades to or closure of surface impoundments or other solid waste
management units, which are required by the Resource Conservation and
Recovery Act, permit;
o upgrades to sulfur removal capabilities, which are required to comply with
mandates adopted by the U.S. Environmental Protection Agency, or "U.S.
EPA," to reduce the sulfur content of diesel fuel and gasoline;
o changes that are required to address a ban on methyl tertiary butyl ether,
or "MTBE," and other ether-based gasoline additives; and
o changes that will be required to comply with the terms of a potential
settlement agreement with the U.S. EPA of alleged violations of the New
Source Review provisions of the federal Clean Air Act of 1990, or the
"Clean Air Act."
Our refineries produce gasolines that meet the current requirements for
conventional and reformulated gasolines under the Clean Air Act and its
implementing regulations. Our refineries also produce low-sulfur diesel fuel
meeting federal standards. In February 2000, the U.S. EPA published the Tier 2
Motor Vehicle Emission Standards and Gasoline Sulfur Control Requirements for
all passenger vehicles, establishing standards for reduced sulfur content in
gasoline. The ruling mandates that the average sulfur content of gasoline at any
refinery not exceed 30 parts per million, or ppm, during any calendar year by
January 1, 2006. Starting in 2004, the U.S. EPA will begin a program to phase in
new low sulfur gasoline. In addition, in January 2001, the U.S. EPA issued its
rule to reduce the sulfur content of diesel fuel sold to highway consumers by
97%, from 500 ppm to 15 ppm, beginning June 1, 2006. Lawsuits by refining
industry groups have been filed that may delay implementation of the diesel rule
beyond 2006. Compliance with the new Tier 2 specifications for the reduction of
sulfur in both gasoline and distillates is expected to cost the refining
industry over $8 billion.
Several states in our marketing areas have banned or limited the use of
oxygenated ethers, such as MTBE, in gasoline. For example, New York has banned
gasoline containing MTBE effective January 1, 2004. Other states and the U.S.
EPA are also considering use restrictions on those ethers. Our refineries
currently produce and use the oxygenated ether MTBE in reformulated gasoline to
comply with requirements in federal law for 2% oxygen content. If use of this
ether is further banned or limited, we will have to make significant changes to
be able to sell reformulated gasoline into markets affected by these
restrictions. The nature, extent and costs of these changes depend on the nature
and extent of the restrictions on oxygenated ethers, whether the federal
oxygenate mandate remains in place and other laws and regulations relating to
fuels. In addition, the cost to produce diesel and gasoline fuels will increase
as a result of sulfur or aromatics reductions or a ban of oxygenated ethers. We
cannot assure that we will be able to recover the increased cost of production
through increases in the price of our refined products.
Several states in our market areas have adopted regional or statewide
restrictions on the properties of gasoline distributed in those areas, and other
standards have been proposed. We may not be able to make gasoline for such local
markets depending on the standards imposed without additional capital
investment. Investments we may make to meet either local or federal fuel
standards are made subject to market conditions and economic justification.
Several bills are pending before the U.S. Congress which would mandate that
the gasoline pool be made up of a specified percentage of "renewable fuels,"
which would likely be ethanol. We cannot predict the extent and requirements of
any renewable fuels program or the potential effects of such a program on our
operations. Any requirement that we use ethanol or achieve a specific level of
renewable fuels in our gasoline pool could impose significant costs on us.
We expect that the nature of the refining business will continue to make it
subject to increasingly stringent environmental and other laws and regulations
that may increase the costs of operating our refineries above currently
projected levels and require future capital expenditures, including increased
costs associated with more stringent standards for air emissions, wastewater
discharges and the remediation of contamination. It is difficult to predict the
effect of future laws and regulations on our financial condition or results of
operations. We cannot assure that environmental or health and safety liabilities
and expenses will not have a material adverse effect on our financial condition
or results of operations.
PERMITTING AND REGULATORY MATTERS MAY IMPACT THE OPERATION OF OUR REFINERIES.
We are required to obtain certain permits and to comply with constantly
changing provisions of numerous statutes and regulations relating to, among
other things:
21
o business operations,
o the safety and health of employees and the public,
o the environment,
o employment,
o hiring and anti-discrimination, and
o limitations on noise.
New statutes and regulations or new permit provisions may become applicable
to our refineries, resulting in the imposition of significant additional costs.
Failure to comply with any of these permits, statutes and regulatory
requirements may result in significant civil or criminal liability and, in
certain circumstances, the temporary or permanent curtailment or shutdown of all
or part of our operations or the inability to produce marketable products. We
cannot assure that we will at all times be in compliance with all applicable
statutes and regulations or have all necessary permits. Furthermore, our failure
to be in compliance at all times with applicable regulations also could
adversely affect our financial condition or results of operations.
COMPETITORS WHO PRODUCE THEIR OWN SUPPLY OF FEEDSTOCKS, MAKE ALTERNATIVE FUELS
OR HAVE GREATER FINANCIAL RESOURCES MAY HAVE A COMPETITIVE ADVANTAGE OVER US.
The refining industry is highly competitive with respect to both feedstock
supply and refined product markets. We compete with numerous other companies for
available supplies of crude oil and other feedstocks and for outlets for our
refined products. We are not engaged in the petroleum exploration and production
business and therefore do not produce any of our crude oil feedstocks.
Competitors that have their own production are at times able to offset losses
from refining operations with profits from production operations, and may be
better positioned to withstand periods of depressed refining margins or
feedstock shortages. A number of our competitors have greater financial and
other resources than we do. These competitors have a greater ability to bear the
economic risks inherent in all phases of the refining industry. Some of our
competitors have more efficient refineries and may have lower per barrel crude
oil refinery processing costs. In addition, we compete with other industries
that provide alternative means to satisfy the energy and fuel requirements of
our industrial, commercial and individual consumers. If we are unable to compete
effectively with these competitors, our financial condition, results of
operations, and business prospects could be materially adversely affected.
OUR OPERATIONS ARE INHERENTLY SUBJECT TO DISCHARGES OR OTHER RELEASES OF
PETROLEUM OR HAZARDOUS SUBSTANCES FOR WHICH WE MAY FACE SIGNIFICANT LIABILITIES.
Our operations, as with others in the businesses in which we operate, are
inherently subject to spills, discharges or other releases of petroleum or
hazardous substances that may give rise to liability to governmental entities or
private parties under federal, state or local environmental laws, as well as
under common law. We could incur substantial costs in connection with these
liabilities, including clean-up costs, fines and civil or criminal sanctions,
and personal injury or property damage claims. Spills, discharges or other
releases of contaminants have occurred from time to time during the normal
course of our operations, including releases associated with our refineries and
pipeline operations, as well as releases at gasoline service stations and other
petroleum product distribution facilities we have operated and are operating. We
cannot assure you that additional spills, discharges and other releases will not
occur in the future, that governmental agencies will not assess penalties
against us in connection with any past or future discharges or incidents, or
that third parties will not assert claims against us for damages allegedly
arising out of any such past or future discharges or incidents.
TERRORIST ATTACKS AND THREATS OR ACTUAL WAR MAY NEGATIVELY IMPACT OUR BUSINESS,
FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
Our business is affected by general economic conditions and fluctuations in
consumer confidence and spending, which can decline as a result of numerous
factors outside of our control. Recent terrorist attacks in the United States,
as well as events occurring in response to or in connection with them, including
future terrorist attacks against United States targets, rumors or threats of
war, actual conflicts involving the United States or its allies, or military or
trade disruptions impacting our suppliers or our customers, may adversely impact
our operations. As a result, there could be delays or losses in the delivery of
supplies and raw materials to us, decreased sales of our products and extension
of time for payment of accounts receivable from our customers. Strategic targets
such as energy-related assets (which could include refineries such as ours) may
be at greater risk of future terrorist attacks than other targets in the United
States. These occurrences could have an adverse impact on energy prices,
including prices for our products, and an adverse impact on the margins from our
refining and marketing operations. In addition, disruption or significant
increases in energy prices could result in government-imposed price controls.
Any or a combination of these occurrences could have a material adverse effect
on our business, financial condition and results of operations.
22
USE OF PROCEEDS
On February 27, 2003, we issued and sold the outstanding notes. We will not
receive any proceeds from the issuance of the exchange notes in the exchange
offer. We will cancel all of the outstanding notes tendered in the exchange
offer. The net proceeds from the sale of the outstanding notes, after deducting
the discount paid to the initial purchasers and offering expenses, were
approximately $535 million. We used a portion of the net proceeds to repurchase
$50 million in principal amount of our 7-7/8% senior notes due 2006 and used the
balance thereof to pay a portion of a dividend of $500 million to PDV America to
provide funds for the repayment of PDV America's 7-7/8% senior notes due August
1, 2003.
CAPITALIZATION
The following table shows our debt and capitalization as of June 30, 2003.
This table should be read in conjunction with "Management's Discussion and
Analysis of Financial Condition and Results of Operations -- Liquidity and
Capital Resources," the financial statements and related notes, and other
financial information included elsewhere in this prospectus.
<Table>
<Caption>
AS OF JUNE 30, 2003
--------------------
(IN MILLIONS)
Debt, including current portion:
Revolving bank loans(1) ......................... $ --
Senior Secured Term Loan ........................ 200.0
11 3/8% Senior Notes due 2011 ................... 546.7
7 7/8% Senior Notes due 2006 .................... 149.9
9.30% Senior Notes due 2003 to 2006 ............. 45.6
7.17-8.94% Master Shelf Notes due 2004 to 2009 .. 185.0
Tax-exempt bonds due 2004 to 2032 ............... 327.4
Taxable bonds due 2028 .......................... 25.0
Total capital lease obligations ................. 35.9
--------------------
Total debt, including current portion ............ $ 1,515.5
====================
Shareholder's equity ............................. $ 2,809.0
====================
Total capitalization ............................. $ 4,324.5
====================
</Table>
- ----------
(1) Additional borrowings of up to approximately $518 million were
available for general corporate purposes under our committed revolving
credit facilities as of June 30, 2003.
SELECTED CONSOLIDATED FINANCIAL AND OPERATING DATA
The following selected financial data for the years ended and as of
December 31, 2000, 2001 and 2002 are derived from our audited consolidated
financial statements, including the notes thereto, appearing elsewhere in this
prospectus. The following selected financial data for the years ended and as of
December 31, 1998 and 1999 are derived from audited consolidated financial
statements, including the notes thereto, not included in this prospectus. The
data for the years ended and as of December 31, 1998, 1999, 2000 and 2001 have
been restated to give retroactive effect to the contribution by PDV America of
the VPHI common stock to us. The primary asset of VPHI is a fuels refinery in
Lemont, Illinois. This table should be read in conjunction with "Management's
Discussion and Analysis of Financial Condition and Results of Operations" and
our financial statements, including the notes thereto, appearing elsewhere in
this prospectus.
23
<Table>
<Caption>
YEAR ENDED DECEMBER 31, SIX MONTHS ENDED JUNE 30,
------------------------------------------------------------- -------------------------
1998 1999 2000 2001 2002 2003 2002
--------- --------- --------- --------- --------- ----------- ----------
(AS RESTATED)(1)
------------------------------------------------
(IN MILLIONS, EXCEPT AS NOTED)
STATEMENT OF INCOME DATA:
Net sales and sales to affiliates ..... $10,960.2 $13,334.4 $22,157.2 $19,601.2 $19,358.3 $12,396.7 $ 8,464.9
Equity in earnings of affiliates ...... 82.3 22.2 58.7 108.9 101.3 44.6 49.3
Other income (expense) (including
insurance recoveries) ............. (12.3) (29.0) (26.0) (5.2) 386.9 160.0 196.0
Cost of sales and operating
expenses .......................... 10,305.6 12,804.2 21,370.3 18,734.7 19,211.3 12,017.0 8,395.8
Selling, general and
administrative expenses ........... 254.3 239.1 226.6 292.1 284.9 137.3 151.3
Interest expense ...................... 101.0 94.6 85.6 69.2 67.4 55.9 33.2
Capital lease interest charge ......... 14.2 12.7 11.0 9.1 7.0 2.8 3.8
Minority interest ..................... 1.2 0.2 1.8 2.0 -- -- --
Income taxes .......................... 128.2 54.2 182.6 206.2 95.9 139.8 45.4
Cumulative effect of accounting
change ............................ -- -- -- 13.6 -- -- --
--------- --------- --------- --------- --------- --------- ---------
Net income (loss) ..................... $ 225.7 $ 122.6 $ 312.0 $ 405.2 $ 180.0 $ 248.5 $ 80.7
--------- --------- --------- --------- --------- --------- ---------
CASH FLOW DATA:
Operating activities .................. $ 671.1 $ 196.2 $ 803.3 $ 584.5 $ 818.3 $ 326.7 $ 121.7
Investing activities .................. (221.9) (249.0) (153.7) (292.8) (788.9) (224.7) (420.0)
Financing activities .................. (446.7) 116.7 (727.6) (206.3) (100.7) 111.3 212.8
--------- --------- --------- --------- --------- --------- ---------
Increase (decrease) during the
period ............................ $ 2.5 $ 63.9 $ (78.0) $ 85.4 $ (71.3) $ 213.3 $ (85.5)
--------- --------- --------- --------- --------- --------- ---------
SELECTED OPERATING DATA:(2)
Refining capacity (000's of barrels
per day) .......................... 637 637 644 644 644 644 644
Crude oil throughput (000's of
barrels per day) .................. 588 592 620 569 543 624 520
Total throughput (000's of barrels
per day) .......................... 718 707 750 698 654 757 642
Utilization (%) ....................... 92% 93% 96% 88% 84% 97% 81%
Wholesale fuel sales (millions of
gallons) .......................... 13,029 13,143 13,441 13,566 13,758 7,036 6,833
</Table>
<Table>
BALANCE SHEET DATA (AT PERIOD END):
Current assets ........................ $ 1,570.8 $ 2,247.6 $ 2,597.8 $ 2,287.0 $ 2,187.5 $ 2,455.3 $ 2,353.4
Current liabilities ................... 1,198.6 1,578.3 2,147.0 1,530.8 1,999.1 1,632.3 2,156.4
--------- --------- --------- --------- --------- --------- ---------
Working capital ....................... $ 372.2 $ 669.3 $ 450.8 $ 756.2 $ 188.4 $ 823.0 $ 197.0
Net property, plant and equipment ..... 3,419.9 3,417.7 3,287.2 3,292.5 3,750.2 3,829.2 3,505.3
Total assets .......................... 6,028.1 6,642.0 6,805.7 6,509.1 6,986.9 7,308.6 6,893.8
Total debt ............................ 1,524.8 1,694.1 1,198.6 1,478.9 1,347.5 1,515.5 1,570.0
Total shareholder's equity ............ 2,222.2 2,385.1 2,476.2 2,401.3 2,559.2 2,809.0 2,482.2
OTHER FINANCIAL DATA:
Capital expenditures(3) ............... $ 230.2 $ 248.0 $ 122.0 $ 253.5 $ 711.8 $ 208.7 $ 350.0
Depreciation and amortization ......... 261.8 274.0 290.5 288.9 298.7 162.8 145.0
EBITDA(4) ............................. 730.9 558.1 881.7 978.6 649.0 609.8 308.1
Ratio of total debt to EBITDA(4) ...... 2.1x 3.0x 1.4x 1.5x 2.1x 2.5x 5.1x
Ratio of EBITDA to interest
expense(4) ........................ 6.3x 5.2x 9.1x 12.5x 8.7x 10.4x 8.3x
Total debt to book
capitalization .................... 40.7% 41.5% 32.6% 38.1% 34.5% 35.0% 38.7%
Ratio of earnings to fixed
charges(5) ........................ 3.82x 2.89x 5.62x 7.08x 3.66x 5.15x 3.56x
</Table>
- ----------
(1) Amounts shown for the years ended December 31, 1998, 1999, 2000 and
2001 have been restated to give effect to the contribution to our
capital of the common stock of VPHI, which indirectly owns the Lemont,
Illinois refinery, as if it took place on January 1, 1998. The
combination actually occurred on January 1, 2002.
(2) Refining data for Lake Charles, Corpus Christi and Lemont refineries.
(3) 2002 capital expenditures include $220 million in spending to rebuild
the crude unit at our Lemont refinery due to a fire in 2001.
(4) EBITDA is defined as net income plus interest expense, income taxes,
depreciation and amortization. EBITDA is used as a measure of
performance by management and is not a measure of performance under
generally accepted accounting principles, or GAAP. While EBITDA should
not be considered as a substitute for net income, cash flows from
operating activities and other income or cash flow statement data
prepared in accordance with GAAP, or as a measure of profitability or
liquidity, we disclose it because management understands that EBITDA is
customarily used by certain investors as one measure of a company's
ability to service debt. Because EBITDA is not calculated identically
by all companies, our presentation may not be comparable to similarly
titled measures presented by other companies.
24
Shown below is a reconciliation between EBITDA for each of the years
presented in the table and our net income for those years, as reflected
earlier in the table and in our financial statements:
<Table>
<Caption>
YEAR ENDED DECEMBER 31, SIX MONTHS ENDED JUNE 30,
--------------------------------------------------------------- -------------------------
(IN MILLIONS) 1998 1999 2000 2001 2002 2003 2002
----------- ----------- ----------- ----------- ----------- ----------- -----------
EBITDA $ 730.9 $ 558.1 $ 881.7 $ 978.6 $ 649.0 $ 609.8 $ 308.1
less Interest expense 101.0 94.6 85.6 69.2 67.4 55.9 33.2
less Capital lease interest charge 14.2 12.7 11.0 9.1 7.0 2.8 3.8
less Income taxes 128.2 54.2 182.6 206.2 95.9 139.8 45.4
less Depreciation and amortization 261.8 274.0 290.5 288.9 298.7 162.8 145.0
----------- ----------- ----------- ----------- ----------- ----------- -----------
Net income $ 225.7 $ 122.6 $ 312.0 $ 405.2 $ 180.0 $ 248.5 $ 80.7
=========== =========== =========== =========== =========== =========== ===========
</Table>
EBITDA for the year ended December 31, 2002 includes the effect of $314
million of business interruption insurance recoveries and $78 million
of property damage insurance recoveries that exceeded the net book
value of the property destroyed and related expenses. These insurance
recoveries were related to a fire occurring at our Lemont refinery in
August 2001 and the resulting shutdown of such refinery until May of
2002 for cleanup and rebuild.
(5) For the purposes of calculating the ratio of earnings to fixed charges,
"earnings" consist of income before income taxes and cumulative effect
of accounting changes plus fixed charges (excluding capitalized
interest), amortization of previously capitalized interest and certain
adjustments to equity in income of affiliates. "Fixed charges" include
interest expense, capitalized interest, amortization of debt issuance
costs and a portion of operating lease rent expense deemed to be
representative of interest.
25
MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
OVERVIEW
The following discussion of our financial condition and results of
operations should be read in conjunction with our financial statements attached
as an appendix to this prospectus.
Petroleum refining industry operations and profitability are influenced by
a large number of factors, some of which individual petroleum refining and
marketing companies cannot control. Governmental regulations and policies,
particularly in the areas of taxation, energy and the environment, have a
significant impact on petroleum activities, regulating how companies conduct
their operations and formulate their products. See "Business -- Environment and
Safety." Demand for crude oil and refined products is largely driven by the
condition of local and worldwide economies, although weather patterns and
taxation relative to other energy sources also play a significant part. Our
consolidated operating results are affected by these industry-specific factors
and by company-specific factors, such as the success of marketing programs and
refinery operations.
The earnings and cash flows of companies engaged in the refining and
marketing business in the United States are primarily dependent upon producing
and selling quantities of refined products at margins sufficient to cover fixed
and variable costs. The refining and marketing business is characterized by high
fixed costs resulting from the significant capital outlays associated with
refineries, terminals and related facilities. This business is also
characterized by substantial fluctuations in variable costs, particularly costs
of crude oil, feedstocks and blending components, and in the prices realized for
refined products. Crude oil and refined products are commodities whose price
levels are determined by market forces beyond our control.
In general, prices for refined products are significantly influenced by the
price of crude oil, feedstocks and blending components. Although an increase or
decrease in the price for crude oil, feedstocks and blending components
generally results in a corresponding increase or decrease in prices for refined
products, generally there is a lag in the realization of the corresponding
increase or decrease in prices for refined products. The effect of changes in
crude oil prices on our consolidated operating results therefore depends in part
on how quickly refined product prices adjust to reflect these changes. Although
the pricing formulas under our crude supply agreements with PDVSA are designed
to provide a measure of stability to our refining margins, we receive only
approximately 50% of our crude oil requirements under these agreements.
Therefore, a substantial or prolonged increase in crude oil prices without a
corresponding increase in refined product prices, or a substantial or prolonged
decrease in refined product prices without a corresponding decrease in crude oil
prices, or a substantial or prolonged decrease in demand for refined products
could have a significant negative effect on our earnings and cash flows.
As noted under "Business" below, we purchase a significant amount of our
crude oil requirements for our Lake Charles, Corpus Christi, Paulsboro and
Savannah refineries from PDVSA under long-term supply agreements (expiring in
the years 2006 through 2013). This supply represented approximately 50% of the
crude oil processed in those refineries in the year ended December 31, 2002.
These crude supply agreements contain force majeure provisions which entitle
PDVSA to reduce the quantity of crude oil and feedstocks delivered under the
crude supply agreements under specified circumstances. For the years 2001 and
2002, PDVSA deliveries of crude oil to us were less than contractual base
volumes due to PDVSA's declaration of force majeure pursuant to all of the
long-term crude oil supply contracts related to our refineries. Therefore, we
were required to obtain alternative sources of crude oil, which resulted in
lower operating margins.
A nation-wide work stoppage by opponents of the government of Venezuela
began on December 2, 2002, and disrupted most activity in that country,
including the operations of PDVSA. We were able to locate and purchase 100% of
our crude oil requirements in December 2002 and January and February 2003,
albeit at higher prices than under our supply contracts with PDVSA, to maintain
normal operations at our refineries and to meet our refined products commitments
to our customers. The reduction in supply from PDVSA and the increase in
purchases of crude oil from alternative sources had the effect of increasing our
crude oil cost and decreasing our gross margin and profit margin from what it
would have been if the crude oil were received under our long-term crude oil
supply contracts with PDVSA. We received only 43% of our contracted crude oil
from PDVSA under the supply contracts in December 2002. As a result, we estimate
that crude oil costs for the month of December 2002 were $20 million higher than
what would have otherwise been the case. Since January 2003 we have received
100% of our contracted crude volumes under those supply agreements. In addition,
we have purchased approximately 9.6 million barrels of crude oil from Venezuela
at market prices. We were notified that effective March 6, 2003 PDVSA ended its
declaration of force majeure under the crude oil supply agreements.
We also purchase significant volumes of refined products to supplement the
production from our refineries to meet marketing demands and to resolve
logistical issues. Our earnings and cash flows are also affected by the cyclical
nature of petrochemical prices. As a result of the factors described above, our
earnings and cash flows may experience substantial fluctuations. Inflation was
not a significant factor in our operations during the three years ended December
31, 2002.
26
The cost and available coverage level of property and business interruption
insurance to us is driven, in part, by company specific and industry factors. It
is also affected by national and international events. The present environment
for us is one characterized by increased cost of coverage, higher deductibles,
and some restrictions in coverage terms. This has the potential effect of
lowering our profitability in the near term.
CRITICAL ACCOUNTING POLICIES
The preparation of financial statements in conformity with Accounting
Principles Generally Accepted in the United States of America requires that
management apply accounting policies and make estimates and assumptions that
affect results of operations and the reported amounts of assets and liabilities.
The following areas are those that we believe are important to our financial
statements and which require significant judgment and estimation because of
inherent uncertainty.
Environmental Expenditures. The costs to comply with environmental
regulations are significant. Environmental expenditures incurred currently that
relate to present or future revenues are expensed or capitalized as appropriate.
Expenditures that relate to an existing condition caused by past operations and
that do not contribute to current or future revenue generation are expensed. We
constantly monitor our compliance with environmental regulations and respond
promptly to issues raised by regulatory agencies. We record liabilities when
environmental assessments and/or cleanups are probable and the costs can be
reasonably estimated. We do not discount environmental liabilities to their
present value. We record environmental liabilities without consideration of
potential recoveries from third parties. Subsequent adjustments to estimates, to
the extent required, may be made as more refined information becomes available.
Commodity and Interest Rate Derivatives. We enter into petroleum futures
contracts, options and other over-the-counter commodity derivatives, primarily
to reduce our inventory purchase and product sale exposure to market risk. In
the normal course of business, we also enter into certain petroleum commodity
forward purchase and sale contracts, which qualify as derivatives. We also enter
into various interest rate swap agreements to manage our risk related to
interest rate changes on our debt. Effective January 1, 2001, we record fair
values of derivatives in other current assets or other current liabilities, as
applicable, and changes in the fair value of derivatives not designated in
hedging relationships in income. Effective January 1, 2001, our policy is to
elect hedge accounting only under limited circumstances involving derivatives
with initial terms of 90 days or greater and notional amounts of $25 million or
greater. We will continue to review our accounting treatment of derivatives and
may elect hedge accounting under certain circumstances in the future.
Litigation and Injury Claims. Various lawsuits and claims arising in the
ordinary course of business are pending against us. The status of these lawsuits
and claims are continually reviewed by external and internal legal counsel.
These reviews provide the basis for which we determine whether or not to record
accruals for potential losses. Accruals for losses are recorded when, in
management's opinion, such losses are probable and reasonably estimable. If
known lawsuits and claims were to be determined in a manner adverse to us, and
in amounts greater than our accruals, then such determinations could have a
material adverse effect on our results of operations in a given reporting
period.
Health Care Costs. The cost of providing health care to current employees
and retired employees continues to increase at a significant rate. Historically,
we have absorbed the majority of these cost increases which reduce profitability
and increase our liability. There is no indication that the trend in health care
costs will be reversed in future periods. Our liability for such health care
costs is based on actuarial calculations that could be subject to significant
revision as the underlying assumptions regarding future health care costs and
interest rates change.
Pensions. Our pension cost and liability are based on actuarial
calculations, which are dependent on assumptions concerning discount rates,
expected rates of return on plan assets, employee turnover, estimated retirement
dates, salary levels at retirement and mortality rates. In addition, differences
between actual experience and the assumptions also affect the actuarial
calculations. While management believes that the assumptions used are
appropriate, differences in actual experience or changes in assumptions may
significantly affect our future pension cost and liability.
CHANGE IN REPORTING ENTITY
On January 1, 2002, PDV America, our direct parent company, made a
contribution to our capital of all of the common stock of PDV America's wholly
owned subsidiary, VPHI. Effective January 1, 2002, the accounts of VPHI were
included in our consolidated financial statements at the historical carrying
value of PDV America's investment in VPHI. In the following discussion and
analysis of financial condition and results of operations, amounts shown for the
years ended December 31, 2001 and 2000 have been restated to give effect to this
transaction as if it took place on January 1, 2000.
27
RESULTS OF OPERATIONS
FOR THE SIX MONTHS ENDED JUNE 30, 2003 AND 2002
The following table summarizes the sources of our sales revenues and sales
volumes for the six-month periods ended June 30, 2003 and 2002:
SALES REVENUES AND VOLUMES
<Table>
<Caption>
SIX MONTHS
ENDED JUNE 30,
-------------------------------------------------
2003 2002 2003 2002
------- ------- ------- -------
(IN MILLIONS) (GALLONS IN MILLIONS)
Gasoline ............................ $ 6,896 $ 5,069 7,354 6,958
Jet fuel ............................ 938 632 1,094 1,004
Diesel/#2 fuel ...................... 2,870 1,540 3,283 2,492
Asphalt ............................. 276 223 358 354
Petrochemicals and industrial
products ....................... 1,083 674 1,253 1,038
Lubricants and waxes ................ 291 279 127 128
------- ------- ------- -------
Total refined product sales .... $12,354 $ 8,417 13,469 11,974
Other sales and adjustments ......... 43 48 -- --
------- ------- ------- -------
Total sales .................... $12,397 $ 8,465 13,469 11,974
======= ======= ======= =======
</Table>
The following table summarizes our cost of sales and operating expenses for
the six-month periods ended June 30, 2003 and 2002:
COST OF SALES AND OPERATING EXPENSES
<Table>
<Caption>
SIX MONTHS
ENDED JUNE 30,
---------------------
2003 2002
------- -------
(IN MILLIONS)
Crude oil .................................................. $ 3,386 $ 2,186
Refined products ........................................... 6,832 4,680
Intermediate feedstocks .................................... 939 752
Refining and manufacturing costs ........................... 640 586
Other operating costs and expenses and inventory changes ... 220 192
------- -------
Total cost of sales and operating expenses ............ $12,017 $ 8,396
======= =======
</Table>
Sales revenues and volumes. Sales increased $3.9 billion, or approximately
46%, in the six-month period ended June 30, 2003. This increase was due to an
increase in average sales price of 30% and an increase in refined product sales
volume of 12%. (See Sales Revenues and Volumes table above.)
Equity in earnings of affiliates. Equity in earnings of affiliates
decreased $4.7 million for the six-month period ended June 30, 2003 as compared
to the same period in 2002. The decrease was primarily due to the decrease in
the earnings of LYONDELL-CITGO, our share of which decreased $7 million. The
decrease in LYONDELL-CITGO's earnings was primarily due to the write-off of
refinery project costs and higher fuel costs offset in part by higher margins
during the first six-months of 2003. This decrease was offset by the increase in
the earnings of The Needle-Coker Company, our share of which increased $2
million.
Insurance recoveries. The insurance recoveries of $144 million included in
the six months ended June 30, 2003 relate primarily to a fire which occurred on
August 14, 2001 at the Lemont refinery. The crude unit was destroyed and the
refinery's other processing units were temporarily taken out of production.
These recoveries are, in part, reimbursements for expenses incurred in 2002 and
2001 to mitigate the effect of the fire on our earnings. In July 2003, we
received the final payment of approximately $19 million.
Cost of sales and operating expenses. Cost of sales and operating expenses
increased by $3.6 billion or 43%, in the six months ended June 30, 2003 as
compared to the same period in 2002. (See Cost of Sales and Operating Expenses
table above.)
28
We purchase refined products to supplement the production from our
refineries to meet marketing demands and resolve logistical issues. Refined
product purchases represented 57% and 56% of total cost of sales and operating
expenses for the first six-months of 2003 and 2002, respectively. We estimate
margins on purchased products, on average, are lower than margins on produced
products due to the fact that we can only receive the marketing portion of the
total margin received on the produced refined products. However, purchased
products are not segregated from our produced products and margins may vary due
to market conditions and other factors beyond our control. As such, it is not
practical to measure the effects on profitability of changes in volumes of
purchased products. In the near term, other than normal refinery turnaround
maintenance, we do not anticipate operational actions or market conditions which
might cause a material change in anticipated purchased product requirements;
however, there could be events beyond our control which impact the volume of
refined products purchased. (See also "Forward Looking Statements.")
Gross margin. The gross margin for the six-month period ended June 30, 2003
was approximately 2.8 cents per gallon, compared to approximately 0.6 cents per
gallon for the same period in 2002. In the six-month period ended June 30, 2003,
the revenue per gallon component increased approximately 30% and the cost per
gallon component increased approximately 27%. As a result, the gross margin
increased approximately 2.2 cents on a per gallon basis in the six months ended
June 30, 2003 compared to the same period in 2002. The gross margin is directly
affected by changes in selling prices relative to changes in costs. An increase
or decrease in the price for crude oil, feedstocks and blending products
generally results in a corresponding increase or decrease in prices for refined
products. Generally, the effect of changes in crude oil and feedstock prices on
our consolidated operating results therefore depends in part on how quickly
refined product prices adjust to reflect these changes. However, in the first
half of 2002, there was a substantial decrease in sales price without an
equivalent decrease in refined product costs resulting in a significant negative
impact on our gross margin and earnings.
Selling, general and administrative expenses. Selling, general and
administrative expenses decreased 9% from $151 million in the first six months
of 2002 to $137 million in the same period in 2003. The decrease in selling,
general and administrative expenses is related primarily to a decrease in legal
and related expenses and settlements during the six-month period ended June 30,
2003.
Interest expense. Interest expense increased $22 million in the six-month
period ended June 30, 2003 as compared to the same period in 2002. This was
primarily due to the net increase in the outstanding debt balance and higher
overall interest rates resulting from the issuance of the $550 million senior
notes and the closing of the $200 million secured term loan in February 2003.
FOR THE THREE YEARS ENDED DECEMBER 31, 2002
The following table summarizes our sales revenues and volumes.
SALES REVENUES AND VOLUMES
<Table>
<Caption>
YEAR ENDED DECEMBER 31, YEAR ENDED DECEMBER 31,
----------------------------------- -----------------------------------
2002 2001 2000 2002 2001 2000
------- ------- ------- ------- ------- -------
(IN MILLIONS) (GALLONS IN MILLIONS)
Gasoline .................................. $11,758 $11,316 $12,447 15,026 13,585 13,648
Jet fuel .................................. 1,402 1,660 2,065 2,003 2,190 2,367
Diesel/#2 fuel ............................ 3,462 3,984 4,750 5,031 5,429 5,565
Asphalt ................................... 597 502 546 902 946 812
Petrochemicals and industrial products .... 1,485 1,490 1,763 2,190 2,297 2,404
Lubricants and waxes ...................... 561 536 552 261 240 279
------- ------- ------- ------- ------- -------
Total refined product sales .......... $19,265 $19,488 $22,123 25,413 24,687 25,075
Other sales ............................... 93 113 34 -- -- --
------- ------- ------- ------- ------- -------
Total sales .......................... $19,358 $19,601 $22,157 25,413 24,687 25,075
======= ======= ======= ======= ======= =======
</Table>
The following table summarizes our cost of sales and operating expenses.
29
COST OF SALES AND OPERATING EXPENSES
<Table>
<Caption>
YEAR ENDED DECEMBER 31,
-----------------------------------
2002 2001 2000
------- ------- -------
(IN MILLIONS)
Crude oil .................................................. $ 5,098 $ 4,898 $ 6,784
Refined products ........................................... 11,077 10,686 11,638
Intermediate feedstocks .................................... 1,489 1,496 1,573
Refining and manufacturing costs ........................... 1,233 1,113 1,058
Other operating costs and expenses and inventory changes ... 314 542 317
------- ------- -------
Total cost of sales and operating expenses ........... $19,211 $18,735 $21,370
======= ======= =======
</Table>
RESULTS OF OPERATIONS
2002 COMPARED TO 2001
Sales revenues and volumes. Sales decreased $243 million, representing a 1%
decrease from 2001 to 2002. This was due to a decrease in average sales price of
4% offset by an increase in sales volume of 3%. (See Sales Revenues and Volumes
table above.)
Equity in earnings of affiliates. Equity in earnings of affiliates
decreased by approximately $8 million, or 7% from $109 million in 2001 to $101
million in 2002. An increase in earnings of $4 million attributable to
LYONDELL-CITGO was more than offset by a $12 million reduction in earnings from
our other investments. For the year ended December 31, 2002, LYONDELL-CITGO
constituted a significant investment for us in a 50 percent or less owned person
under SEC regulations. See separate financial statements for LYONDELL-CITGO
attached as an appendix to this prospectus.
Insurance recoveries. The insurance recoveries of $407 million and $53
million included in the years ended December 31, 2002 and 2001, respectively,
relate primarily to a fire which occurred on August 14, 2001 at the Lemont
refinery. These recoveries are, in part, reimbursements for expenses incurred in
2002 and 2001 to mitigate the effect of the fire on our earnings. We expect to
recover additional amounts related to this event subject to final settlement
negotiations.
Other income (expense), net. Other income (expense) increased $38 million,
or 66% from $(58) million in 2001 to $(20) million in 2002. The increase is due
primarily to the fact that during 2001, we recorded property losses and related
expenses totaling $54 million in other income (expense) related to fires at the
Lemont refinery and the Lake Charles refinery.
Cost of sales and operating expenses. Cost of sales and operating expenses
increased by $476 million, or 3%, from 2001 to 2002. (See Cost of Sales and
Operating Expenses table above.)
We purchase refined products to supplement the production from our
refineries to meet marketing demands and resolve logistical issues. The refined
product purchases represented 58% of cost of sales for 2002 and 57% for 2001.
These refined product purchases included purchases from LYONDELL-CITGO and
HOVENSA, L.L.C. ("HOVENSA"). We estimate that margins on purchased products, on
average, are lower than margins on produced products due to the fact that we can
only receive the marketing portion of the total margin received on the produced
refined products. However, purchased products are not segregated from our
produced products and margins may vary due to market conditions and other
factors beyond our control. As such, it is difficult to measure the effects on
profitability of changes in volumes of purchased products. In the near term,
other than normal refinery turnaround maintenance, we do not anticipate
operational actions or market conditions which might cause a material change in
anticipated purchased product requirements; however, there could be events
beyond our control which impact the volume of refined products purchased. (See
also "Forward Looking Statements.")
As a result of purchases of crude oil supplies from alternate sources due
to PDVSA's invocation of the force majeure provisions in its crude oil supply
contracts, we estimate that our cost of crude oil purchased in 2002 increased by
$42 million from what would have otherwise been the case.
Gross margin. The gross margin for 2002 was $147 million, or 0.8% of net
sales, compared to $867 million, or 4.4% of net sales, for 2001. The gross
margin decreased from 3.5 cents per gallon in 2001 to 0.6 cents per gallon in
2002 as a result of general market conditions and factors relating specifically
to us including operating problems, weather related shut downs and crude oil
supply disruptions under contracts with PDVSA.
30
Selling, general and administrative expenses. Selling, general and
administrative expenses decreased $7 million, or 2% in 2002, primarily as a
result of a decrease in compensation offset in part by increases in marketing
expenses.
Interest Expense. Interest expense decreased $2 million, or 3% in 2002,
primarily due to the decline in interest rates on our variable rate debt.
Income taxes. Our provision for income taxes in 2002 was $96 million,
representing an effective tax rate of 35%. In 2001, our provision for income
taxes was $206 million, representing an effective tax rate of 35%.
2001 COMPARED TO 2000
Sales revenues and volumes. Sales decreased $2.6 billion, representing a
12% decrease from 2000 to 2001. This was due to a decrease in average sales
price of 11% and a decrease in sales volume of 2%. (See Sales Revenues and
Volumes table above.)
Equity in earnings of affiliates. Equity in earnings of affiliates
increased by approximately $50 million, or 85% from $59 million in 2000 to $109
million in 2001. The increase was primarily due to the change in the earnings of
LYONDELL-CITGO, our share of which increased $33 million, from $41 million in
2000 to $74 million in 2001. LYONDELL-CITGO's increased earnings in 2001 are
primarily due to higher refining margins offset by the impact of lower crude
processing rates due to an unplanned production unit outage and a major
turnaround, and higher natural gas costs in the first quarter of 2001. The
earnings for 2000 were impacted by a major planned turnaround which occurred
during the second quarter of 2000.
Cost of sales and operating expenses. Cost of sales and operating expenses
decreased by $2.6 billion, or 12%, from 2000 to 2001. (See Cost of Sales and
Operating Expenses table above.)
We purchase refined products to supplement the production from our
refineries to meet marketing demands and resolve logistical issues. The refined
product purchases represented 57% and 54% of cost of sales for the years 2001
and 2000. These refined product purchases included purchases from LYONDELL-CITGO
and HOVENSA. We estimate that margins on purchased products, on average, are
lower than margins on produced products due to the fact that we can only receive
the marketing portion of the total margin received on the produced refined
products. However, purchased products are not segregated from our produced
products and margins may vary due to market conditions and other factors beyond
our control. As such, it is difficult to measure the effects on profitability of
changes in volumes of purchased products. In the near term, other than normal
refinery turnaround maintenance, we do not anticipate operational actions or
market conditions which might cause a material change in anticipated purchased
product requirements; however, there could be events beyond our control that
impact the volume of refined products purchased. (See also "Forward Looking
Statements.")
As a result of purchases of crude oil supplies from alternate sources due
to the PDVSA's invocation of the force majeure provisions in our crude oil
supply contracts, we estimate that our cost of crude oil purchased in 2001
increased by $6 million from what would have otherwise been the case.
Gross margin. The gross margin for 2001 was $867 million, or 4.4% of net
sales, compared to $787 million, or 3.5% of net sales, for 2000. The gross
margin increased from 3.1 cents per gallon in 2000 to 3.5 cents per gallon in
2001 as a result of general market conditions.
Selling, general and administrative expenses. Selling, general and
administrative expenses increased $66 million, or 29% in 2001, primarily as a
result of an increase in incentive compensation, promotion expenses, and the
start-up expenses related to an international operation in 2001.
Interest expense. Interest expense decreased $16 million, or 19% in 2001,
primarily due to lower interest rates and lower average debt outstanding during
2001.
Income taxes. Our provision for income taxes in 2001 was $206 million,
representing an effective tax rate of 35%. In 2000, our provision for income
taxes was $183 million, representing an effective tax rate of 37%.
LIQUIDITY AND CAPITAL RESOURCES
Consolidated net cash provided by operating activities totaled
approximately $327 million for the six-month period ended June 30, 2003.
Operating cash flows were derived primarily from net income of $249 million,
depreciation and amortization of $163 million, distributions in excess of equity
in earnings of affiliates of $82 million, increase in deferred taxes of $64
million, and changes in operating assets and liabilities of $(248) million. The
more significant changes in operating assets and liabilities include an increase
in notes and accounts receivable and a decrease in current liabilities offset,
in part, by a decrease in inventory.
31
Consolidated net cash provided by operating activities totaled
approximately $818 million for the year ended December 31, 2002. Operating cash
flows were derived primarily from net income of $180 million, depreciation and
amortization of $299 million and changes in working capital of $258 million. The
change in working capital is primarily the result of increases in payables to
affiliates and trade payables and a decrease in prepaid taxes offset, in part,
by an increase in prepaid turnaround maintenance charges.
Net cash used in investing activities in the six month period ended June
30, 2003 totaled $225 million consisting primarily of capital expenditures of
$209 million. These capital expenditures consisted of:
<Table>
<Caption>
THREE SIX
MONTHS MONTHS
-------- --------
ENDED JUNE 30, 2003
-----------------------
(IN MILLIONS)
Regulatory requirements .......... $ 80 $ 123
Maintenance capital projects ..... 14 32
Strategic capital expenditures ... 25 54
-------- --------
Total capital expenditures ....... $ 119 $ 209
======== ========
</Table>
Net cash used in investing activities in 2002 totaled $789 million
consisting primarily of capital expenditures of $712 million. These capital
expenditures include $220 million in spending to rebuild the crude distillation
unit of the Lemont refinery due to a fire on August 14, 2001. The crude unit was
destroyed and the refinery's other processing units were temporarily taken out
of production. The new crude unit was operational in May 2002. Capital
expenditures also include $148 million in spending, primarily at the Lake
Charles and Lemont refineries, to meet regulatory requirements, $116 million in
spending for maintenance capital projects, primarily at the Lake Charles
refinery, and $228 million in strategic capital expenditures, primarily at the
Lake Charles, Corpus Christi and Lemont refineries.
Net cash provided by financing activities totaled $111 million for the
six-month period ended June 30, 2003, consisting primarily of the proceeds from
our 11-3/8% senior notes due in 2011 of $547 million and the proceeds from our
senior secured term loan of $200 million. These proceeds were offset by the
payment of $279 million on revolving bank loans; the repurchase of $50 million
of 7 7/8% senior notes due 2006 for a cash payment of $47.5 million; the payment
of $50 million on master shelf agreement notes; the repurchase of $98 million of
tax-exempt bonds; the repurchase of $90 million of taxable bonds; the repayment
of loans from affiliates of $39 million; $19 million in debt issuance costs
associated with the 11-3/8% senior notes due 2011, the Senior Secured term loan,
and the repurchase of taxable and tax-exempt bonds; and capital lease payments
of $12 million.
Net cash used in financing activities totaled $101 million for the year
2002, consisting primarily of the payment of $112 million on revolving bank
loans, the payment of $25 million on master shelf agreement notes, the payment
of $31 million on taxable bonds, the payment of capital lease obligations of $20
million and the net repayments of other debt of $20 million. These payments were
offset in part by $39 million in proceeds from loans from affiliates and $69
million in proceeds from tax exempt bonds.
As of December 31, 2002, we and our subsidiaries had an aggregate of $1.3
billion of indebtedness outstanding that matures on various dates through the
year 2032. As of December 31, 2002, our contractual commitments to make
principal payments on this indebtedness were $191 million, $47 million and $161
million for 2003, 2004 and 2005, respectively. Our bank credit facilities
consisted of a $260 million, three year, revolving bank loan, a $260 million,
364-day, revolving bank loan, and a $25 million, 364-day, revolving bank loan,
all of which are unsecured and have various borrowing maturities. At December
31, 2002, $279 million was outstanding under these credit agreements. As of
December 31, 2002, our other principal indebtedness consisted of (i) $200
million in senior notes issued in 1996, (ii) $235 million in senior notes issued
pursuant to a master shelf agreement with an insurance company, (iii) $45
million in private placement senior notes issued in 1991, (iv) $426 million in
obligations related to tax exempt bonds issued by various governmental units,
and (v) $115 million in obligations related to taxable bonds issued by various
governmental units. (See Notes 10 and 11 of our financial statements, which are
attached as an appendix to this prospectus.)
As of June 30, 2003, capital resources available to us included cash on
hand totaling $246 million generated by operations and other sources, and
available borrowing capacity under our committed bank facilities of $518
million. Our management believes that we have sufficient capital resources to
carry out planned capital spending programs, including regulatory and
environmental projects in the near term and to meet currently anticipated future
obligations as they arise. We periodically evaluate other sources of capital in
the marketplace and anticipate that long-term capital requirements will be
satisfied with current capital resources and future financing arrangements,
including the issuance of debt securities. Our ability to obtain such financing
will depend on numerous factors, including market conditions and our perceived
creditworthiness at that time. (See also "Forward Looking Statements.")
32
Our various debt instruments require maintenance of a specified minimum net
worth and impose restrictions on our ability to:
o incur additional debt unless we meet specified interest coverage and
debt to capitalization ratios;
o place liens on our property, subject to specified exceptions;
o sell assets, subject to specified exceptions;
o make restricted payments, including dividends, repurchases of capital
stock and specified investments; and
o merge consolidate or transfer assets.
We are in compliance with our covenants under our debt financing
arrangements at June 30, 2003.
Upon the occurrence of a change of control, as defined in the indenture
governing the notes, the holders of the notes have the right to require us to
repurchase them at a price equal to 101% of the principal amount thereof plus
accrued interest. In addition, our bank credit agreements provide that, unless
lenders holding two-thirds of the commitments thereunder otherwise agree, a
change of control, as defined in those agreements, will constitute a default
under those credit agreements.
As of December 31, 2002, capital expenditure projected amounts for 2003 and
2004 through 2007 are as follows:
CAPITAL EXPENDITURES -- 2003 THROUGH 2007
<Table>
<Caption>
2004-
2003 2007
PROJECTED(1) PROJECTED
------------ ------------
(IN MILLIONS)
Strategic ................... $ 88 $ 535
Maintenance ................. 91 502
Regulatory/environmental .... 269 1,037
------------ ------------
Total .................. $ 448 $ 2,074
============ ============
</Table>
- ----------
(1) Reflects reduction in 2003 projected capital expenditures discussed
below. These estimates may change as future regulatory events unfold.
See "Forward Looking Statements."
Estimated capital expenditures as of December 31, 2002 necessary to comply
with the Clean Air Act and other environmental laws and regulations are
summarized below. See "Forward Looking Statements."
<Table>
<Caption>
BEYOND
2003 2004 2005 2006 2006
-------- -------- -------- -------- --------
(IN MILLIONS)
Tier 2 gasoline(1) ................ $ 231 $ 125 $ 82 $ 10 $ --
Ultra low sulfur diesel(2) ........ 3 33 179 155 249
Other environmental(3) ............ 35 51 81 92 81
-------- -------- -------- -------- --------
Total regulatory/environmental .... $ 269 $ 209 $ 342 $ 257 $ 330
======== ======== ======== ======== ========
</Table>
- ----------
(1) In February 2000, the EPA promulgated the Tier 2 Motor Vehicle Emission
Standards Final Rule for all passenger vehicles, establishing standards
for sulfur content in gasoline. These regulations mandate that the
average sulfur content of gasoline for highway use produced at any
refinery not exceed 30 parts per million during any calendar year by
January 1, 2006, with a phase-in beginning January 1, 2004. In order to
comply with these regulations, CITGO will install additional
hydroprocessing facilities at its refineries. (Hydroprocessing
facilities remove sulfur from oil by means of a chemical reaction which
occurs when the oil is mixed with hydrogen, heated and processed over a
catalyst.)
(2) Spending on Ultra Low Sulfur Diesel ("ULSD") assumes the EPA will
require ULSD for on-road diesel in 2006 and ULSD for off-road diesel
use in 2008. The ULSD program will require CITGO to make additional
capital investments at its refineries. The estimates shown here are
based on the installation of traditional hydroprocessing facilities.
These regulations are not final and spending could be reduced if
certain alternative regulatory schemes proposed by EPA are adopted.
CITGO continues to evaluate new technological innovations which may
reduce the required investment.
(3) Other environmental spending assumes $162.9 million in spending to
comply with New Source Review standards under the Clean Air Act.
Internally generated cash flow, together with borrowings available under
our credit facilities, are expected to be sufficient to fund capital
expenditures during the remainder of 2003. In addition, we have taken steps to
reduce our capital expenditures in 2003 by
33
approximately $250 million, resulting in budgeted total 2003 expenditures of
$460 million, and will reassess the economics of the postponed projects at a
later date. We accomplished this reduction in capital expenditures by
authorizing no new discretionary spending for 2003, suspending discretionary
projects already underway where practical and delaying maintenance and
regulatory projects. In addition, two major refinery maintenance turnarounds
were delayed past 2003 so capital spending for these projects was also delayed.
Of the $250 million spending reduction, 60% was discretionary, 27% was
maintenance of the business and 13% was regulatory. The regulatory and
maintenance of the business projects will be completed under a delayed schedule.
Discretionary spending will be restarted as funds become available. Finally, we
are continuing to review the timing and amount of scheduled expenditures under
our planned capital spending programs, including regulatory and environmental
projects in the near term.
We are required by various state regulations to demonstrate financial
responsibility for environmental liability coverage, closure and post-closure
care related to our facilities. Historically, we have satisfied the requirements
based upon the credit rating of our bonds and various financial ratios. Although
our credit rating and 2002 financial ratios did not satisfy the requirements of
Louisiana, since December 2002 our credit ratings have been raised and our
financial ratios have improved. We have filed a request for a variance from the
Louisiana regulations and are awaiting the state's response. We believe that we
will meet these requirements at year end.
We are a member of the PDV Holding consolidated Federal income tax return.
We have a tax allocation agreement with PDV Holding, which is designed to
provide PDV Holding with sufficient cash to pay its consolidated income tax
liabilities. (See Note 1 and Note 5 of our financial statements, which are
attached as an appendix to this prospectus).
The sources of our liquidity changed in late 2002 and early 2003 as a
result of the events that occurred in Venezuela during that period of time.
Those events affected a portion of the crude oil supplies that we received from
PDVSA, requiring us to replace those supplies from other sources at higher
prices and on payment terms generally less favorable than the terms under our
supply agreements with PDVSA. However, PDVSA allowed extended payment terms
during this period. Since January 2003 we have received 100% of our contracted
crude volumes under those supply agreements. In addition, we have purchased
approximately 9.6 million barrels of crude oil from Venezuela at market prices.
We were notified that effective March 6, 2003 PDVSA ended its declaration of
force majeure under the crude oil supply agreements. During the supply
disruption, we were successful in covering any shortfall with spot market
purchases. A number of trade creditors tightened credit payment terms on
purchases. That tightening increased our cash needs and reduced our liquidity.
By late March 2003, some trade creditors eased their credit restrictions, and by
mid 2003, credit terms had returned to normal.
In addition, all three major rating agencies lowered our credit ratings
based upon, among other things, concerns regarding the supply disruption. One of
the downgrades caused a termination event under our existing accounts
receivables sale facility, which ultimately led to the repurchase of $125
million in accounts receivable and the cancellation of the facility on January
31, 2003. That facility had a maximum size of $225 million, of which $125
million was used at the time of cancellation. In the ordinary course of business
we maintain uncommitted short-term lines of credit with several commercial
banks. Effective following the debt ratings downgrade, these uncommitted lines
of credit are not currently available. Our committed revolving credit facilities
remain available.
We have outstanding letters of credit that support taxable and tax-exempt
bonds that were issued previously for our benefit. Some of the providers of
these outstanding letters of credit have indicated that they will not renew such
letters of credit. As a result, in 2003 through June 30, we repurchased $90
million of taxable bonds and $138 million of tax-exempt bonds that were
supported by these letters of credit. We expect that we will seek to reissue
these bonds, with replacement letters of credit in support, if we are able to
obtain such letters of credit from other financial institutions or,
alternatively, we will seek to replace these bonds with new bonds that will not
require letter of credit support. As of August 1, 2003, we have an additional
$61 million of letters of credit outstanding that back or support other bond
issues that we have issued through governmental entities, which are subject to
renewal during the period ending June 30, 2004. We have not received any notice
from the issuers of these additional letters of credit indicating an intention
not to renew. We cannot be certain that any of our letters of credit will be
renewed, that we will be successful in obtaining replacements if they are not
renewed, that any replacement letters of credit will be on terms as advantageous
as those we currently hold or that we will be able to arrange for replacement
bonds that will not require letter of credit support. To the extent that issuers
of these letters of credit do not renew, we are not successful in obtaining
replacements if they are not renewed, or that we are not successful in arranging
for replacement bonds that will not require letter of credit support, this will
increase our cash needs and reduce our liquidity. We believe that we have and
will continue to have sufficient liquidity to accommodate any of these potential
outcomes.
In August 2002, three of our affiliates entered into agreements to advance
excess cash to us from time to time under demand notes. These notes provide for
maximum amounts of $10 million from PDV Texas, Inc., $30 million from PDV
America and $10 million from PDV Holding. Amounts outstanding on these notes at
December 31, 2002 were $5 million, $30 million and $4 million from PDV Texas,
PDV America and PDV Holding, respectively. At June 30, 2003, there was no
outstanding balance on these notes.
Operating cash flow represents a primary source for meeting our liquidity
requirements; however, the termination of our accounts receivable sale facility,
the possibility of additional tightened payment terms early in the year and the
possible need to replace non-
34
renewing letters of credit prompted us to undertake arrangements to supplement
and improve our liquidity. In 2003 to date, we have undertaken the following:
o On February 27, 2003, we issued $550 million principal amount of the
outstanding notes.
o On February 27, 2003, we closed on a three year $200 million senior
loan secured by our 15.8 percent equity interest in Colonial Pipeline
and our 6.8 percent equity interest in Explorer Pipeline.
o On February 28, 2003, a new accounts receivable sales facility was
established. This facility allows for the non-recourse sale of certain
accounts receivable to independent third parties. A maximum of $200
million in accounts receivable may be sold at any one time.
o On April 25, 2003, we completed a transaction that will provide
approximately $50 million of liquidity from the transfer of title to a
third party of certain of our refined products at the time those
products are delivered into the custody of interstate pipelines. The
terms of this transaction include an option to acquire like volumes of
refined products from the third party at prevailing prices at
predetermined transfer points. The transfer of title to certain
refined products began in May 2003.
o We have reduced our planned capital expenditures in 2003 by
approximately $250 million.
Our senior unsecured debt ratings, which apply to the outstanding notes and
we expect will apply to our exchange notes, as currently assessed by the three
major debt rating agencies, are as follows:
Moody's Investor's Services Ba3
Standard & Poor's Ratings Group BB
Fitch Investors Services, Inc. BB-
On May 9, 2003, Standard & Poor's Ratings Group ("S&P") upgraded our senior
unsecured debt rating to BB-. S&P upgraded our senior unsecured debt rating to
BB on July 31, 2003 and Fitch Investors Services, Inc. ("Fitch") upgraded our
senior unsecured debt rating to BB- on August 8, 2003.
Our secured debt ratings, as currently assessed by the three major debt
rating agencies, are as follows:
Moody's Investor's Services Ba2
Standard & Poor's Ratings Group BB+
Fitch Investors Services, Inc. BB+
On May 9, 2003, S&P upgraded our secured debt rating to BB. S&P upgraded
our secured debt rating to BB+ on July 31, 2003 and Fitch upgraded our secured
debt rating to BB+ on August 8, 2003.
These ratings reflect only the views of these rating agencies, and an
explanation of the significance of these ratings may be obtained only from these
rating agencies by contacting: Moody's Corporation, 99 Church Street, New York,
New York 10007, Standard & Poor's Ratings Group,
ratings_request@standardpoors.com or 212-438-2400, and Fitch Investors Services,
Inc., Corporate Headquarters, One State Street Plaza, New York, New York 10004.
There is no assurance that these ratings will, in fact, be assigned or remain in
effect for any period of time or that they will not be revised downward or
withdrawn entirely by the rating agencies if, in their judgment, circumstances
warrant.
On February 28, 2003, a new accounts receivable sales facility was
established. This facility allows for the non-recourse sale of certain accounts
receivable to independent third parties. A maximum of $200 million in accounts
receivable may be sold at any one time. The amounts sold under this facility
vary on a daily basis. On August 11, 2003, $200 million of trade receivables
were sold under the facility.
On July 25, 2003 we made a $500 million dividend payment for the purpose of
enabling our parent, PDV America to make the principal payment on $500 million,
7-7/8% senior notes due August 1, 2003. Our $550 million, 11-3/8% senior notes
due 2011 have certain minimum liquidity requirements for payment of such a
dividend and we were in compliance with those requirements on July 25, 2003. Our
liquidity after the dividend on July 25, 2003, was $526 million, comprised of
$518 million in available capacity under our revolving credit facilities and $8
million in cash on hand.
Our debt instruments do not contain any covenants that trigger increased
costs or burdens as a result of a change in our securities ratings. However,
certain of our guarantee agreements, which support approximately $20 million of
PDV Texas, an affiliate, letters of credit, require us to cash collateralize the
applicable letters of credit upon a reduction of our credit rating below a
stated level.
35
As of June 30, 2003, we and our subsidiaries had a total of $1.5 billion of
indebtedness outstanding that matures on various dates through the year 2032:
<Table>
<Caption>
(000's omitted)
Revolving bank loans $ --
Senior Secured Term loan, due 2006 with variable interest rate 200,000
Senior Notes $200 million face amount, due 2006
with interest rate of 7-7/8% 149,934
Senior Notes $550 million face amount, due 2011
with interest rate of 11-3/8% 546,734
Private Placement Senior Notes, due 2003 to 2006
with interest rate of 9.30% 45,455
Master Shelf Agreement Senior Notes, due 2004 to
2009 with interest rates from 7.17% to 8.94% 185,000
Tax-Exempt Bonds, due 2004 to 2032 with variable and
fixed interest rates 327,425
Taxable Bonds, due 2028 with variable interest rates 25,000
----------------
$ 1,479,548
================
</Table>
We believe that we have adequate liquidity from existing sources to support
our operations for the foreseeable future. We are continuing to review our
operations for opportunities to reduce operating and capital expenditures.
CONTRACTUAL OBLIGATIONS AND COMMERCIAL COMMITMENTS
The following table summarizes future payments for our contractual
obligations at December 31, 2002.
CONTRACTUAL OBLIGATIONS AT DECEMBER 31, 2002
<Table>
<Caption>
LESS THAN YEAR YEAR OVER 5
1 YEAR 2-3 4-5 YEARS TOTAL
---------- ---------- ---------- ---------- ----------
(IN MILLIONS)
Long-term debt ....................... $ 191 $ 209 $ 313 $ 588 $ 1,301
Capital lease obligations ............ 23 5 6 13 47
Operating leases ..................... 106 101 35 13 255
---------- ---------- ---------- ---------- ----------
Total contractual cash obligations ... $ 320 $ 315 $ 354 $ 614 $ 1,603
========== ========== ========== ========== ==========
</Table>
For additional information, see Notes 11 and 15 in our consolidated
financial statements for the year ended December 31, 2002, which are attached as
an appendix to this prospectus.
The following table summarizes our contingent commitments at December 31,
2002.
36
OTHER COMMERCIAL COMMITMENTS
AT DECEMBER 31, 2002
<Table>
<Caption>
EXPIRATION
-------------------------------------------------------------
TOTAL
LESS THAN YEAR YEAR OVER 5 AMOUNTS
1 YEAR 2-3 4-5 YEARS COMMITTED
---------- ---------- ---------- ---------- ----------
(IN MILLIONS)
Letters of credit(1) ............ $ 3 $ -- $ -- $ -- $ 3
Guarantees ...................... 67 2 3 1 73
Surety bonds .................... 58 11 2 -- 71
---------- ---------- ---------- ---------- ----------
Total commercial commitments .... $ 128 $ 13 $ 5 $ 1 $ 147
========== ========== ========== ========== ==========
</Table>
- ----------
(1) We have outstanding letters of credit totaling approximately $451
million, which includes $448 million related to our tax-exempt and
taxable revenue bonds included in long-term debt in the table of
contractual obligations above.
For additional information, see Note 14 in our consolidated financial
statements for the year ended December 31, 2002, which are attached as an
appendix to this prospectus.
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Introduction. We have exposure to price fluctuations of natural gas, crude
oil, feedstocks, and refined products as well as fluctuations in interest rates.
To manage these exposures, our management has authorized the use of commodity
derivatives in a Risk Management Program. We do not attempt to manage the price
risk related to all of our inventories and fixed forward commitments. As a
result, at June 30, 2003 and December 31, 2002, we were exposed to the risk of
broad market price movements with respect to a substantial portion of our
current and anticipated commodity needs. We have at least 30 million barrels of
current inventory and fixed forward price contracts at price risk on any given
day. In addition, we have price risk on purchasing 1.8 trillion BTU of natural
gas every month. As of December 31, 2002 our total crude and refined products
inventory was 49 million barrels. Aggregate commodity derivative positions
entered into for price risk management purposes at that date totaled 1.6 million
barrels. As of June 30, 2003 aggregate commodity derivative positions entered
into for price risk management purposes totaled 2.4 million barrels and 3.3
trillion BTU.
Commodity Instruments. We balance our crude oil and petroleum product
supply/demand and manage a portion of our price risk by entering into petroleum
commodity derivatives. Generally, our risk management strategies qualified as
hedges through December 31, 2000. Effective January 1, 2001, our policy is to
elect hedge accounting only under limited circumstances involving derivatives
with initial terms of 90 days or greater and notional amounts of $25 million or
greater. At December 31, 2002 and June 30, 2003, none of our commodity
derivatives were accounted for as hedges.
37
NON TRADING COMMODITY DERIVATIVES
OPEN POSITIONS AT JUNE 30, 2003
<Table>
<Caption>
MATURITY NUMBER OF CONTRACT MARKET
COMMODITY DERIVATIVE DATE CONTRACTS VALUE VALUE(4)
-------------- ----------------------------- -------- ------------ ------------ ------------
LONG/(SHORT) ASSET/(LIABILITY)
------------ --------------------------------
(IN MILLIONS)
No lead
gasoline(1) .... Futures Purchased 2003 20 $ 0.7 $ 0.7
Forward Purchase Contracts 2003 2,058 $ 70.8 $ 72.3
Forward Sales Contracts 2003 (1,493) $ (51.1) $ (53.0)
Distillates(1) ... Futures Purchased 2003 1,035 $ 31.9 $ 34.7
Futures Purchased 2004 666 $ 20.1 $ 21.3
OTC Swaps (Pay Fixed/Receive
Float)(3) 2003 6 $ -- $ --
Forward Purchase Contracts 2003 809 $ 24.9 $ 25.6
Forward Sale Contracts 2003 (782) $ (24.8) $ (25.3)
Crude Oil(1) ..... Futures Purchased 2003 10 $ 0.3 $ 0.3
Futures Sold 2003 (661) $ (19.0) $ (19.7)
Forward Purchase Contracts 2003 1,834 $ 55.3 $ 55.0
Forward Sale Contracts 2003 (697) $ (21.6) $ (21.4)
Natural Gas(2) ... Futures Purchased 2003 230 $ 14.5 $ 12.8
Listed Call Options Purchased 2003 80 $ -- $ 0.5
Listed Put Options Sold 2003 (20) $ -- $ (0.2)
Heat Crack(1) ... OTC Swaps (Pay Fixed/Receive
Float)(3) 2003 725 $ -- $ (0.7)
OTC Swaps (Pay Float/Receive
Fixed)(3) 2003 (725) $ -- $ 0.3
</Table>
- ----------
(1) 1,000 barrels per contract
(2) Ten-thousands of mmbtu per contract
(3) Floating price based on market index designated in contract; fixed
price agreed upon at a date of contract.
(4) Based on actively quoted prices.
38
NON TRADING COMMODITY DERIVATIVES
OPEN POSITIONS AT JUNE 30, 2002
<Table>
<Caption>
MATURITY NUMBER OF CONTRACT MARKET
COMMODITY DERIVATIVE DATE CONTRACTS VALUE VALUE(5)
-------------- ------------------------------- -------- ------------ -------- --------
LONG/(SHORT) ASSET/(LIABILITY)
------------ ------------------------
(IN MILLIONS)
No lead
gasoline(1) .... Futures Purchased 2002 599 $ 19.4 $ 19.8
Futures Sold .................. 2002 (915) $ (30.0) $ (30.1)
OTC Swaps (Pay Floating/Receive
Floating(4) ................ 2002 (25) $ -- $ --
Forward Purchase Contracts .... 2002 3,004 $ 96.0 $ 95.2
Forward Sale Contracts ........ 2002 (4,023) $ (129.1) $ (127.6)
Distillates(1) ... Futures Purchased 2002 1,256 $ 34.5 $ 36.5
Futures Purchased ............. 2003 375 $ 10.2 $ 10.9
Futures Sold .................. 2002 (317) $ (8.9) $ (9.1)
Forward Purchase Contracts .... 2002 1,135 $ 30.7 $ 31.6
Forward Sale Contracts ........ 2002 (1,295) $ (34.7) $ (36.3)
Crude Oil(1) ..... Futures Purchased 2002 250 $ 6.6 $ 6.7
Futures Sold .................. 2002 (1,110) $ (28.7) $ (29.4)
Futures Sold .................. 2003 (400) $ (9.8) $ (10.1)
OTC Swaps (Pay Floating/Receive
Fixed(3) ................... 2002 (1,270) $ -- $ (0.6)
Forward Purchase Contracts .... 2002 8,106 $ 202.0 $ 212.1
Forward Sale Contracts ........ 2002 (4,883) $ (123.5) $ (130.0)
Natural Gas(2) Futures Purchased 2002 300 $ 1.0 $ 1.0
Propane(1) ....... OTC Swaps (Pay Floating/Receive
Fixed(3) ................... 2002 (400) $ -- $ 0.8
OTC Swaps (Pay Floating/Receive
Fixed(3) ................... 2003 (300) $ -- $ 0.6
</Table>
- ----------
(1) 1,000 barrels per contract
(2) Ten-thousands of mmbtu per contract
(3) Floating price based on market index designated in contract; fixed
price agreed upon at date of contract
(4) Pay floating price based on a market index designated in contract;
receive floating price based on a different market index designated in
contract
(5) Based on actively quoted prices
39
NON TRADING COMMODITY DERIVATIVES
OPEN POSITIONS AT DECEMBER 31, 2002
<Table>
<Caption>
MATURITY NUMBER OF CONTRACT MARKET
COMMODITY DERIVATIVE DATE CONTRACTS VALUE VALUE(4)
-------------- ---------------------------- -------- ----------- --------- --------
(IN MILLIONS)
No lead
gasoline(1) .... Futures Purchased 2003 564 $ 19.9 $ 20.6
Futures Sold 2003 1,023 35.3 37.6
Listed Options Purchased 2003 1,225 -- 4.2
Listed Options Sold 2003 2,225 -- (5.5)
Forward Purchase Contracts 2003 2,577 89.2 92.5
Forward Sales Contracts 2003 2,364 81.3 86.2
Distillates(1) ... Futures Purchased 2003 2,227 73.4 78.7
Futures Purchased 2004 31 0.8 0.9
Futures Sold 2003 2,953 93.2 96.7
OTC Options Purchased 2003 66 -- 0.1
OTC Options Sold 2003 66 -- (0.1)
OTC Swaps (Pay Fixed/Receive 2003 12 -- --
Float)(3)
OTC Swaps (Pay Float/Receive 2003 75 -- --
Fixed)(3)
Forward Purchase Contracts 2003 3,134 106.5 111.0
Forward Sales Contracts 2003 2,944 98.1 104.7
Crude Oil(1) ..... Futures Purchased 2003 1,986 51.2 54.5
Futures Sold 2003 1,476 41.8 45.3
Listed Options Purchased 2003 2,250 -- 2.3
Listed Options Sold 2003 3,150 -- (3.1)
OTC Swaps (Pay Float/Receive 2003 3,500 -- (3.0)
Fixed)(3)
Forward Purchase Contracts 2003 5,721 160.8 174.4
Forward Sales Contracts 2003 4,412 129.8 137.2
Natural Gas(2) ... Listed Options Purchased 2003 85 -- 0.1
Listed Options Sold 2003 40 -- 0.1
Propane(1) ....... OTC Swaps (Pay Fixed/Receive 2003 75 -- 0.5
Float)(3)
OTC Swaps (Pay Float/Receive 2003 300 -- (1.5)
Fixed)(3)
</Table>
- ----------
(1) 1,000 barrels per contract
(2) Ten-thousands of mmbtu per contract
(3) Floating price based on market index designated in contract; fixed
price agreed upon at date of contract
(4) Based on actively quoted prices
40
NON TRADING COMMODITY DERIVATIVES
OPEN POSITIONS AT DECEMBER 31, 2001
(AS RESTATED)
<Table>
<Caption>
MATURITY NUMBER OF CONTRACT MARKET
COMMODITY DERIVATIVE DATE CONTRACTS VALUE VALUE(4)
-------------- ---------------------------- -------- ----------- -------- --------
(IN MILLIONS)
No lead
gasoline(1) .... Futures Purchased 2002 994 $ 25.4 $ 25.0
Futures Sold 2002 332 8.3 8.1
Forward Purchase Contracts 2002 4,095 95.8 94.0
Forward Sale Contracts 2002 3,148 71.2 73.2
Distillates(1) ... Futures Purchased 2002 1,483 43.4 34.6
Futures Purchased 2003 94 2.4 2.3
Futures Sold 2002 943 25.3 21.8
OTC Options Purchased 2002 30 -- --
OTC Options Sold 2002 30 (0.1) (0.1)
Forward Purchase Contracts 2002 1,123 25.2 24.9
Forward Sale Contracts 2002 2,536 56.3 56.4
Crude oil(1) ..... Futures Purchased 2002 517 12.6 10.4
Futures Sold 2002 649 12.7 12.9
OTC Swaps (Pay Float/Receive 2002 2 -- 0.3
Fixed)(3)
OTC Swaps (Pay Fixed/Receive 2002 1 -- --
Float)(3)
Forward Purchase Contracts 2002 6,652 130.3 135.2
Forward Sale Contracts 2002 6,268 135.1 137.0
Natural gas(2) ... Futures Sold 2002 55 1.6 1.4
OTC Options Sold 2002 20 -- (0.1)
</Table>
- ----------
(1) 1,000 barrels per contract
(2) Ten-thousands of mmbtu per contract
(3) Floating price based on market index designated in contract; fixed
price agreed upon at date of contract
(4) Based on actively quoted prices
Debt Related Instruments. We have fixed and floating U.S. currency
denominated debt. We use interest rate swaps to manage our debt portfolio toward
a benchmark of 40 to 70 percent fixed rate debt to total fixed and floating rate
debt. These instruments have the effect of changing the interest rate with the
objective of minimizing our long-term costs. At June 30, 2003 and 2002 and
December 31, 2002 and 2001, our primary exposures were to LIBOR and floating
rates on tax exempt bonds.
For interest rate swaps, the table below presents notional amounts and
interest rates by expected (contractual) maturity dates. Notional amounts are
used to calculate the contractual payments to be exchanged under the contracts.
NON TRADING INTEREST RATE DERIVATIVES
OPEN POSITIONS AT JUNE 30, 2003 AND 2002 AND DECEMBER 31, 2002 AND 2001
<Table>
<Caption>
FIXED RATE NOTIONAL PRINCIPAL
VARIABLE RATE INDEX EXPIRATION DATE PAID AMOUNT
- ------------------- ---------------- ---------- ------------------
(IN MILLIONS)
J. J. Kenny ....... February 2005 5.30% $ 12
J. J. Kenny ....... February 2005 5.27% $ 15
J. J. Kenny ....... February 2005 5.49% $ 15
------------------
$ 42
</Table>
Interest expense includes $0.6 million in 2000 related to the net
settlements on these agreements. Effective January 1, 2001, changes in the fair
value of these agreements are recorded in other income (expense). The fair value
of the interest rate swap agreements in place at June 30, 2003 and December 31,
2002, based on the estimated amount that we would receive or pay to terminate
the agreements as of that date and taking into account current interest rates,
was a loss of $3 million and $3.5 million, respectively, the offset of which is
recorded in the balance sheet caption other current liabilities.
41
For debt obligations, the table below presents principal cash flows and
related weighted average interest rates by expected maturity dates. Weighted
average variable rates are based on implied forward rates in the yield curve at
the reporting date.
DEBT OBLIGATIONS
AT JUNE 30, 2003
<Table>
<Caption>
EXPECTED
FIXED RATE AVERAGE FIXED VARIABLE RATE AVERAGE VARIABLE
EXPECTED MATURITIES DEBT INTEREST RATE DEBT INTEREST RATE
- ----------------------------- ------------------ ------------------ ------------------ ------------------
(IN MILLIONS) (IN MILLIONS)
2003 ........................ $ 11 9.30% $ -- --
2004 ........................ 31 8.02% 16 6.24%
2005 ........................ 11 9.30% -- --
2006 ........................ 201 8.10% 200 7.05%
2007 ........................ 50 8.94% 12 7.63%
Thereafter .................. 769 10.32% 177 10.21%
------------------ ------------------ ------------------ ------------------
Total ....................... $ 1,073 9.75% $ 405 8.42%
================== ================== ================== ==================
Fair Value .................. $ 1,154 $ 405
================== ==================
</Table>
DEBT OBLIGATIONS
AT JUNE 30, 2002
<Table>
<Caption>
EXPECTED
FIXED RATE AVERAGE FIXED VARIABLE RATE AVERAGE VARIABLE
EXPECTED MATURITIES DEBT INTEREST RATE DEBT INTEREST RATE
- ----------------------------------- ------------------ ------------------ ------------------ ------------------
(IN MILLIONS) (IN MILLIONS)
2002 .............................. $ 11 9.30% $ 130 3.20%
2003 .............................. 61 8.79% 470 4.20%
2004 .............................. 31 8.02% 16 5.15%
2005 .............................. 11 9.30% -- --
2006 .............................. 251 8.06% -- --
Thereafter ........................ 160 7.88% 492 7.99%
------------------ ------------------ ------------------ ------------------
Total ............................. $ 525 8.14% $ 1,108 5.78%
================== ================== ================== ==================
Fair Value ........................ $ 551 $ 1,108
================== ==================
</Table>
42
DEBT OBLIGATIONS
AT DECEMBER 31, 2002
<Table>
<Caption>
EXPECTED
FIXED RATE AVERAGE FIXED VARIABLE RATE AVERAGE VARIABLE
EXPECTED MATURITIES DEBT INTEREST RATE DEBT INTEREST RATE
- ----------------------------------- ---------------- ---------------- ---------------- ----------------
(IN MILLIONS) (IN MILLIONS)
2003 .............................. $ 61 8.79% $ 129 2.60%
2004 .............................. 31 8.02% 16 3.78%
2005 .............................. 11 9.30% 150 5.77%
2006 .............................. 252 8.06% -- --
2007 .............................. 50 8.94% 12 8.76%
Thereafter ........................ 183 7.50% 405 10.22%
---------------- ---------------- ---------------- ----------------
Total ............................. $ 588 8.06% $ 712 7.73%
================ ================ ================ ================
Fair Value ........................ $ 567 $ 712
================ ================
</Table>
DEBT OBLIGATIONS
AT DECEMBER 31, 2001
(AS RESTATED)
<Table>
<Caption>
EXPECTED
AVERAGE
FIXED RATE AVERAGE FIXED VARIABLE RATE VARIABLE
EXPECTED MATURITIES DEBT INTEREST RATE DEBT INTEREST RATE
- ----------------------------------- ---------------- ---------------- ---------------- ----------------
(IN MILLIONS) (IN MILLIONS)
2002 .............................. $ 36 8.78% $ 71 3.45%
2003 .............................. 61 8.79% 320 4.64%
2004 .............................. 31 8.02% 16 5.72%
2005 .............................. 11 9.30% -- --
2006 .............................. 251 8.06% -- --
Thereafter ........................ 130 7.85% 485 8.50%
---------------- ---------------- ---------------- ----------------
Total ............................. $ 520 8.17% $ 892 6.66%
================ ================ ================ ================
Fair Value ........................ $ 532 $ 892
================ ================
</Table>
NEW ACCOUNTING STANDARDS
In July 2001, the Financial Accounting Standards Board ("FASB") issued
Statement of Financial Accounting Standards No. 142, "Goodwill and Other
Intangible Assets" ("SFAS No. 142"), which is fully effective in fiscal years
beginning after December 15, 2001, although certain provisions of SFAS No. 142
are applicable to goodwill and other intangible assets acquired in transactions
completed after June 30, 2001. SFAS No. 142 addresses financial accounting and
reporting for acquired goodwill and other intangible assets and requires that
goodwill and intangibles with an indefinite life no longer be amortized but
instead be periodically reviewed for impairment. The adoption of SFAS No. 142
did not materially impact our financial position or results of operations.
On January 1, 2003 we adopted Statement of Financial Accounting Standards
No. 143, "Accounting for Asset Retirement Obligations" ("SFAS No. 143"), which
addresses financial accounting and reporting for obligations associated with the
retirement of tangible long-lived assets and the associated asset retirement
costs. It applies to legal obligations associated with the retirement of
long-lived assets that result from the acquisition, construction, development
and (or) the normal operation of a long-lived asset, except for certain
obligations of lessees. We have identified certain asset retirement obligations
that are within the scope of the standard, including obligations imposed by
certain state laws pertaining to closure and/or removal of storage tanks,
contractual removal obligations included in certain easement and right-of-way
agreements associated with our pipeline operations, and contractual removal
obligations relating to a refinery processing unit located within a third-party
entity's facility. We cannot currently determine a reasonable estimate of the
fair value of our asset retirement obligations due to the fact that the related
assets have indeterminate useful lives which preclude development of assumptions
about the potential timing of settlement dates. Such obligations will be
recognized in the period in which sufficient information exists to estimate a
range of potential settlement dates. Accordingly, the adoption of SFAS No. 143
did not impact our financial position or results of operations.
In August 2001, the FASB issued Statement of Financial Accounting Standards
No. 144, "Accounting for the Impairment or Disposal of Long-Lived Assets" ("SFAS
No. 144"), which addresses financial accounting and reporting for the impairment
or disposal of long-lived assets by requiring that one accounting model be used
for long-lived assets to be disposed of by sale, whether previously held and
used or newly acquired, and by broadening the presentation of discontinued
operations to include more disposal transactions. SFAS No. 144 is effective for
financial statements issued for fiscal years beginning after December 15, 2001,
and interim periods within those fiscal years. The adoption of SFAS No. 144 did
not impact our financial position or results of operations.
43
In November 2002, the FASB issued Interpretation No. 45, "Guarantor's
Accounting and Disclosure Requirements for Guarantees, Including Indirect
Guarantees of Indebtedness of Others." This interpretation elaborates on the
disclosures to be made by a guarantor in its financial statements about its
obligations under certain guarantees that it has issued. It also requires a
guarantor to recognize, at the inception of a guarantee, a liability for the
fair value of the obligations it has undertaken in issuing the guarantee. The
initial recognition and initial measurement provisions of the interpretation are
applicable on a prospective basis to guarantees issued or modified after
December 31, 2002. The disclosure requirements were effective for financial
statements of interim or annual periods ending after December 15, 2002.
In January 2003, the FASB issued Interpretation No. 46, "Consolidation of
Variable Interest Entities" ("FIN 46"), which clarifies the application of
Accounting Research Bulletin No. 51, "Consolidated Financial Statements." FIN 46
defines variable interest entities and how an enterprise should assess its
interests in a variable interest entity to decide whether to consolidate that
entity. The interpretation requires certain minimum disclosures with respect to
variable interest entities in which an enterprise holds significant variable
interests but which it does not consolidate. FIN 46 applies immediately to
variable interest entities created after January 31, 2003, and to variable
interest entities in which an enterprise obtains an interest after that date. It
applies in the first fiscal year or interim period beginning after June 15, 2003
to variable interest entities in which an enterprise holds a variable interest
that it acquired before February 1, 2003. FIN 46 applies to public enterprises
as of the beginning of the applicable interim or annual period, and it applies
to nonpublic enterprises as of the end of the applicable annual period. FIN 46
may be applied prospectively with a cumulative-effect adjustment as of the date
on which it is first applied or by restating previously issued financial
statements for one or more years with a cumulative-effect adjustment as of the
beginning of the first year restated. We expect that the application of FIN 46
to variable interest entities in which we acquired an interest before February
1, 2003 will not have a material impact on our financial position or results of
operations.
In April 2003, the FASB issued Statement of Financial Accounting Standards
No. 149, "Amendment of Statement 133 on Derivative Instruments and Hedging
Activities" ("SFAS No. 149"). The changes in SFAS No. 149 improve financial
reporting by requiring that contracts with comparable characteristics be
accounted for similarly. Those changes will result in more consistent reporting
of contracts as either derivatives or hybrid instruments. SFAS No. 149 is
effective for contracts entered into or modified after June 30, 2003, except for
certain issues from SFAS No. 133 which have been effective for fiscal quarters
that began prior to June 15, 2003 and for hedging relationships designated after
June 30, 2003. In addition, all provisions of SFAS No. 149 should be applied
prospectively. We have not yet determined the impact of the adoption of SFAS No.
149 on our financial position or results of operations.
PROPOSED ACCOUNTING CHANGE
The American Institute of Certified Public Accountants ("AICPA") has issued
a "Statement of Position" exposure draft on cost capitalization that is expected
to require companies to expense the non-capital portion of major maintenance
costs as incurred. The statement is expected to require that any existing
unamortized deferred non-capital major maintenance costs be expensed
immediately. This statement also has provisions which will change the method of
determining depreciable lives. The impact on future depreciation expense is not
determinable at this time. The exposure draft indicates that the effect of
expensing existing unamortized deferred non-capital major maintenance costs will
be reported as a cumulative effect of an accounting change in the consolidated
statement of income. The final accounting requirements are not known at this
time. At June 30, 2003 and December 31, 2002, we had included turnaround costs
of $186 million and $210 million, respectively, in other assets. Our management
has not determined the amount, if any, of these costs that could be capitalized
under the provisions of the exposure draft.
44
BUSINESS
OVERVIEW
We are a direct wholly-owned operating subsidiary of PDV America, a
wholly-owned subsidiary of PDV Holding. Our ultimate parent is Petroleos de
Venezuela, S.A., the national oil company of the Bolivarian Republic of
Venezuela. We are engaged in the refining, marketing and transportation of
petroleum products including gasoline, diesel fuel, jet fuel, petrochemicals,
lubricants, asphalt and refined waxes, mainly within the continental United
States east of the Rocky Mountains.
Our transportation fuel customers include primarily CITGO branded
independent wholesale marketers, major convenience store chains and airlines
located mainly east of the Rocky Mountains. We generally market asphalt to
independent paving contractors on the East and Gulf Coasts and in the Midwest of
the United States. We sell lubricants principally in the United States to
independent marketers, mass marketers and industrial customers. We sell
lubricants, gasoline, and distillates in various Latin American markets. We sell
petrochemical feedstocks and industrial products to various manufacturers and
industrial companies throughout the United States. We sell petroleum coke
primarily in international markets.
On January 1, 2002, PDV America made a contribution to our capital of all
of the common stock of VPHI. Effective January 1, 2002, the accounts of VPHI
were included in our consolidated financial statements at the historical
carrying value of PDV America's investment in VPHI. Amounts shown for the years
ended December 31, 2001 and 2000 have been restated to give effect to this
transaction as if it took place on January 1, 2000.
The principal asset of VPHI is a 167 thousand barrels per day ("MBPD")
petroleum refinery owned by its wholly-owned subsidiary, PDV Midwest Refining
L.L.C. ("PDVMR"), located in Lemont, Illinois. We have operated this refinery
and purchased substantially all of its primary output, consisting of
transportation fuels and petrochemicals, since May 1997. We plan to continue to
operate the refinery as a source of supply for transportation fuels and
petrochemicals.
COMPETITIVE NATURE OF THE PETROLEUM REFINING BUSINESS
The petroleum refining industry is cyclical and highly volatile, reflecting
capital intensity with high fixed and low variable costs. Petroleum industry
operations and profitability are influenced by a large number of factors, over
some of which individual petroleum refining and marketing companies have little
control. Governmental regulations and policies, particularly in the areas of
taxation, energy and the environment, have a significant impact on how companies
conduct their operations and formulate their products. Demand for crude oil and
its products is largely driven by the condition of local and worldwide
economies, although weather patterns and taxation relative to other energy
sources also play significant parts. Generally, U.S. refiners compete for sales
on the basis of price, brand image and, in some areas, product quality.
REFINING
Our aggregate net interest in rated crude oil refining capacity is 865
MBPD. The following table shows the capacity of each refinery in which we hold
an interest and our share of such capacity as of December 31, 2002.
CITGO REFINING CAPACITY
<Table>
<Caption>
TOTAL
RATED NET CITGO SOLOMON
CRUDE OWNERSHIP PROCESS
CITGO REFINING IN REFINING COMPLEXITY
OWNER INTEREST CAPACITY CAPACITY RATING
-------------- ---------- ----------- ----------- ----------
(%) (MBPD) (MBPD)
LOCATION
Lake Charles, LA ............................. CITGO 100 320 320 17.7
Corpus Christi, TX ........................... CITGO 100 157 157 16.3
Lemont, IL ................................... CITGO 100 167 167 11.7
Paulsboro, NJ ................................ CITGO 100 84 84 --
Savannah, GA ................................. CITGO 100 28 28 --
Houston, TX .................................. LYONDELL-CITGO 41 265 109 15.0
---------- ----------
Total rated crude oil refining capacity .... 1,021 865
========== ==========
</Table>
Our Lake Charles, Corpus Christi and Lemont refineries and the Houston
refinery each have the capability to process large volumes of heavy crude oil
into a flexible slate of refined products. They have Solomon Process Complexity
Ratings of 17.7, 16.3, 11.7 and 15.0, respectively, as compared to an average of
13.9 for U.S. refineries in the most recently available Solomon Associates,
45
Inc. survey. The rating is an industry measure of a refinery's ability to
produce higher value products, with a higher rating indicating a greater
capability to produce such products.
The following table shows our aggregate interest in refining capacity,
refinery input, and product yield for the three years ended December 31, 2002
and the six months ended June 30, 2003.
CITGO REFINERY PRODUCTION(1)
<Table>
<Caption>
YEAR ENDED DECEMBER 31, SIX MONTHS ENDED JUNE 30,
--------------------------------------------------- --------------------------------
2002 2001 2000 2003 2002
------------- ------------- ------------- ------------- -------------
(MBPD, EXCEPT AS OTHERWISE INDICATED)
Rated refining crude
capacity at year/period end ....... 865 865 865 865 865
Refinery input
Crude oil ....................... 674 84% 737 83% 791 83% 792 84% 683 82%
Other feedstocks ................ 131 16% 150 17% 157 17% 151 16% 145 18%
---- ---- ---- ---- ---- ---- ---- ---- ---- ----
Total ......................... 805 100% 887 100% 948 100% 943 100% 828 100%
==== ==== ==== ==== ==== ==== ==== ==== ==== ====
Product yield
Light fuels
Gasoline ...................... 379 46% 375 42% 419 44% 415 43% 377 45%
Jet fuel ...................... 76 9% 76 8% 79 8% 73 8% 80 9%
Diesel/#2 fuel ................ 153 19% 172 19% 182 19% 187 20% 145 17%
Asphalt ........................... 16 2% 44 6% 47 5% 40 4% 36 4%
Petrochemicals and
industrial products ............... 194 24% 228 25% 230 24% 243 25% 209 25%
---- ---- ---- ---- ---- ---- ---- ---- ---- ----
Total ......................... 818 100% 895 100% 957 100% 958 100% 847 100%
==== ==== ==== ==== ==== ==== ==== ==== ==== ====
Utilization of rated
refining capacity ................. 78% 85% 91% 92% 79%
</Table>
- ----------
(1) Includes 41.25% of the LYONDELL-CITGO refinery production.
We produce our light fuels and petrochemicals primarily through our Lake
Charles, Corpus Christi and Lemont refineries. Asphalt refining operations are
carried out through our Paulsboro and Savannah refineries. We purchase refined
products from LYONDELL-CITGO, our joint venture refinery in Houston.
Lake Charles, Louisiana Refinery. This refinery has a rated refining
capacity of 320 MBPD and is capable of processing large volumes of heavy crude
oil into a flexible slate of refined products, including significant quantities
of high-octane unleaded gasoline and reformulated gasoline.
The following table shows the rated refining capacity, refinery input and
product yield at the Lake Charles refinery for the three years ended December
31, 2002 and the six months ended June 30, 2003 and 2002.
46
LAKE CHARLES REFINERY PRODUCTION
<Table>
<Caption>
YEAR ENDED DECEMBER 31, SIX MONTHS ENDED JUNE 30,
--------------------------------------------------- --------------------------------
2002 2001 2000 2003 2002
------------- ------------- ------------- ------------- -------------
(MBPD, EXCEPT AS OTHERWISE INDICATED)
Rated refining crude
capacity at year/period end ..... 320 320 320 320 320
Refinery input
Crude oil ..................... 320 92% 317 90% 319 87% 312 85% 323 93%
Other feedstocks .............. 28 8% 37 10% 48 13% 55 15% 24 7%
---- ---- ---- ---- ---- ---- ---- ---- ---- ----
Total ....................... 348 100% 354 100% 367 100% 367 100% 347 100%
==== ==== ==== ==== ==== ==== ==== ==== ==== ====
Product yield
Light fuels
Gasoline .................... 184 51% 175 48% 187 50% 183 48% 183 51%
Jet fuel .................... 68 19% 67 19% 70 19% 64 17% 72 20%
Diesel/#2 fuel .............. 45 13% 62 17% 58 15% 55 15% 46 13%
Petrochemicals and
industrial products ............. 60 17% 57 16% 59 16% 77 20% 58 16%
---- ---- ---- ---- ---- ---- ---- ---- ---- ----
Total ....................... 357 100% 361 100% 374 100% 379 100% 359 100%
==== ==== ==== ==== ==== ==== ==== ==== ==== ====
Utilization of rated
refining capacity ............... 100% 99% 100% 98% 101%
</Table>
The Lake Charles refinery's Gulf Coast location provides it with access to
crude oil deliveries from multiple sources; imported crude oil and feedstock
supplies are delivered by ship directly to the Lake Charles refinery, while
domestic crude oil supplies are delivered by pipeline and barge. In addition,
the refinery is connected by pipelines to the Louisiana Offshore Oil Port and to
terminal facilities in the Houston area through which it can receive crude oil
deliveries. For delivery of refined products, the refinery is connected through
the Lake Charles Pipeline directly to the Colonial and Explorer Pipelines, which
are the major refined product pipelines supplying the northeast and midwest
regions of the United States, respectively. The refinery also uses adjacent
terminals and docks, which provide access for ocean tankers and barges to load
refined products for shipment.
The Lake Charles refinery's main petrochemical products are propylene and
benzene. Industrial products include sulfur, residual fuels and petroleum coke.
The Lake Charles refinery complex also includes a lubricants refinery which
produces high quality oils and waxes, and is one of the few in the industry
designed as a stand-alone lubricants refinery.
Corpus Christi, Texas Refinery. The Corpus Christi refinery processes heavy
crude oil into a flexible slate of refined products. This refinery complex
consists of the East and West Plants, located within five miles of each other.
The following table shows rated refining capacity, refinery input and
product yield at the Corpus Christi refinery for the three years ended December
31, 2002 and the six months ended June 30, 2003 and 2002.
47
CORPUS CHRISTI REFINERY PRODUCTION
<Table>
<Caption>
YEAR ENDED DECEMBER 31, SIX MONTHS ENDED JUNE 30,
--------------------------------------------------- --------------------------------
2002 2001 2000 2003 2002
------------- ------------- ------------- ------------- -------------
(MBPD, EXCEPT AS OTHERWISE INDICATED)
Rated refining crude
capacity at year/period end .... 157 157 150 157 157
Refinery input
Crude oil .................... 154 73% 154 71% 149 70% 152 70% 155 71%
Other feedstocks ............. 57 27% 64 29% 65 30% 64 30% 63 29%
---- ---- ---- ---- ---- ---- ---- ---- ---- ----
Total ...................... 211 100% 218 100% 214 100% 216 100% 218 100%
==== ==== ==== ==== ==== ==== ==== ==== ==== ====
Product yield
Light fuels
Gasoline ................... 93 44% 90 42% 95 46% 94 44% 95 44%
Diesel/#2 fuel ............. 59 28% 57 26% 58 27% 57 26% 60 28%
Petrochemicals and
industrial products ............ 58 28% 69 32% 58 27% 64 30% 62 28%
---- ---- ---- ---- ---- ---- ---- ---- ---- ----
Total ...................... 210 100% 216 100% 211 100% 215 100% 217 100%
==== ==== ==== ==== ==== ==== ==== ==== ==== ====
Utilization of rated
refining capacity .............. 98% 98% 99% 97% 99%
</Table>
We operate the West Plant under a sublease agreement from Anadarko
Petroleum Corporation. The basic term of the sublease ends on January 1, 2004,
but we may renew the sublease for successive renewal terms through January 31,
2011. We have the right to purchase the West Plant from Anadarko Petroleum
Corporation at the end of the basic term, the end of any renewal term, or on
January 31, 2011 at a nominal price.
The Corpus Christi refinery's main petrochemical products include cumene,
cyclohexane, and aromatics (including benzene, toluene and xylene). Cumene is
used to make phenol, which is a chemical used in the manufacture of plastic and
building materials.
Lemont, Illinois Refinery. The Lemont refinery processes primarily heavy
Canadian crude oil into a flexible slate of refined products.
The following table shows the rated refining capacity, refinery input and
product yield at the Lemont refinery for the three years ended December 31, 2002
and the six months ended June 30, 2003 and 2002.
LEMONT REFINERY PRODUCTION
<Table>
<Caption>
YEAR ENDED DECEMBER 31, SIX MONTHS ENDED JUNE 30,
--------------------------------------------------- --------------------------------
2002 2001 2000 2003 2002
------------- ------------- ------------- ------------- -------------
(MBPD, EXCEPT AS OTHERWISE INDICATED)
Rated refining crude
capacity at year/period end .... 167 167 167 167 167
Refinery input
Crude oil .................... 69 73% 98 78% 153 89% 160 92% 42 55%
Other feedstocks ............. 25 27% 28 22% 18 11% 14 8% 35 45%
---- ---- ---- ---- ---- ---- ---- ---- ---- ----
Total ...................... 94 100% 126 100% 171 100% 174 100% 77 100%
==== ==== ==== ==== ==== ==== ==== ==== ==== ====
Product yield
Light fuels
Gasoline ................... 54 59% 68 56% 89 52% 92 53% 52 67%
Jet fuel ................... -- 0% -- 0% 1 1% 1 1% -- 0%
Diesel/#2 fuel ............. 16 17% 24 20% 40 23% 41 23% 6 8%
Petrochemicals and
industrial products ............ 22 24% 30 24% 41 24% 41 23% 20 25%
---- ---- ---- ---- ---- ---- ---- ---- ---- ----
Total ...................... 92 100% 122 100% 171 100% 175 100% 78 100%
==== ==== ==== ==== ==== ==== ==== ==== ==== ====
Utilization of rated
refining capacity .............. 41% 59% 92% 96% 25%
</Table>
48
Petrochemical products at the Lemont refinery include benzene, toluene and
xylene, plus a range of ten different aliphatic solvents.
On August 14, 2001, a fire occurred at the crude oil distillation unit of
the Lemont refinery. The crude unit was destroyed and the refinery's other
processing units were temporarily taken out of production. A new crude unit was
operational in May 2002. See consolidated financial statements of CITGO for
further information.
LYONDELL-CITGO Refining LP. Subsidiaries of CITGO and Lyondell Chemical
Company ("Lyondell") are partners in LYONDELL-CITGO, which owns and operates a
265 MBPD refinery previously owned by Lyondell and located on the ship channel
in Houston, Texas. At December 31, 2002, our investment in LYONDELL-CITGO was
$518 million. In addition, at December 31, 2002, we held a note receivable from
LYONDELL-CITGO in the approximate amount of $35 million. A substantial amount of
the crude oil processed by this refinery is supplied by PDVSA under a long-term
crude oil supply agreement that expires in the year 2017. For the year ended
December 31, 2002, LYONDELL-CITGO constituted a significant investment for us in
a 50-percent-or-less-owned person under SEC regulations. See separate financial
statements for LYONDELL-CITGO included in this prospectus.
PDVSA invoked its contractual right to declare a force majeure under the
supply agreement with LYONDELL-CITGO at certain points in each of 2002, 2001 and
2000 for varying periods of time for various reasons. As a result of these
declarations, PDVSA was relieved of its obligation to deliver crude oil under
the supply agreement and LYONDELL-CITGO had to purchase crude oil from alternate
sources, which resulted in increased volatility to operating margins.
CRUDE OIL AND REFINED PRODUCT PURCHASES
We do not own any crude oil reserves or production facilities, and must
therefore rely on purchases of crude oil and feedstocks for our refinery
operations. Crude oil is our primary raw material. We buy and sell crude oil to
facilitate procurement and delivery of a desired type or grade of crude oil to a
desired location to supply our refineries, not as an independent business
activity to generate profit. We believe that reflecting the net result of this
activity in cost of sales is an appropriate reflection of the nature of these
transactions as efforts undertaken to acquire raw material. In addition, because
our refinery operations do not produce sufficient refined products to meet the
demands of our marketers, we purchase refined products, primarily gasoline, from
other refiners, including a number of affiliated companies.
Crude Oil Purchases. The following chart shows our net purchases of crude
oil for the three years ended December 31, 2002:
CITGO CRUDE OIL PURCHASES
<Table>
<Caption>
LAKE CHARLES, LA CORPUS CHRISTI, TX LEMONT, IL PAULSBORO, NJ SAVANNAH, GA
------------------- ------------------- ------------------- ------------------- -------------------
2002 2001 2000 2002 2001 2000 2002 2001 2000 2002 2001 2000 2002 2001 2000
----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- -----
(MBPD) (MBPD) (MBPD) (MBPD) (MBPD)
SUPPLIERS
PDVSA ............. 125 136 104 126 138 143 11 13 14 36 39 47 22 22 22
Other sources ..... 190 185 214 29 10 8 62 78 140 7 3 -- -- -- --
----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- -----
Total ........ 315 321 318 155 148 151 73 91 154 43 42 47 22 22 22
===== ===== ===== ===== ===== ===== ===== ===== ===== ===== ===== ===== ===== ===== =====
</Table>
Our largest single supplier of crude oil is PDVSA. We have entered into
long-term crude oil supply agreements with PDVSA with respect to the crude oil
requirements for each of our Lake Charles, Corpus Christi, Paulsboro and
Savannah refineries. The following table shows the base and incremental volumes
of crude oil contracted for delivery and the volumes of crude oil actually
delivered under these contracts in the three years ended December 31, 2002.
CITGO CRUDE OIL SUPPLY CONTRACTS WITH PDVSA
<Table>
<Caption>
VOLUMES OF
CRUDE OIL PURCHASED
CONTRACT CRUDE FOR THE YEAR ENDED
OIL VOLUME DECEMBER 31,
-------------------------------- ------------------------------------------------- CONTRACT
EXPIRATION
BASE INCREMENTAL(1) 2002 2001 2000 DATE
--------------- --------------- --------------- --------------- --------------- ---------------
(MBPD) (MBPD) (YEAR)
LOCATION
Lake Charles, LA(2) ...... 120 70 109 117 110 2006
Corpus Christi, TX(2) .... 130 -- 114 126 118 2012
Paulsboro, NJ(2) ......... 30 -- 27 26 28 2010
Savannah, GA(2) .......... 12 -- 12 12 12 2013
</Table>
49
- ----------
(1) The supply agreement for the Lake Charles refinery gives PDVSA the
right to sell to us incremental volumes up to the maximum amount
specified in the table, subject to certain restrictions relating to the
type of crude oil to be supplied, refining capacity and other
operational considerations at the refinery.
(2) Volumes purchased as shown on this table do not equal purchases from
PDVSA (shown in the previous table) as a result of transfers between
refineries of contract crude purchases included here and spot purchases
from PDVSA which are included in the previous table.
These crude oil supply agreements require PDVSA to supply minimum
quantities of crude oil and other feedstocks to us for a fixed period. The
supply agreements differ somewhat for each entity and each refinery but
generally incorporate formula prices based on the market value of a slate of
refined products deemed to be produced from each particular grade of crude oil
or feedstock, less
o specified deemed refining costs;
o specified actual costs, including transportation charges, actual cost of
natural gas and electricity, import duties and taxes; and
o a deemed margin, which varies according to the grade of crude oil or
feedstock delivered.
Under each supply agreement, deemed margins and deemed costs are adjusted
periodically by a formula primarily based on the rate of inflation. Because
deemed operating costs and the slate of refined products deemed to be produced
for a given barrel of crude oil or other feedstock do not necessarily reflect
the actual costs and yields in any period, the actual refining margin we earn
under the various supply agreements will vary depending on, among other things,
the efficiency with which we conduct our operations during such period.
The price we pay for crude oil purchased under these crude oil supply
agreements is not directly related to the market price of any other crude oil.
However, the intention of the pricing mechanism in the crude supply agreements
was to reflect market pricing over long periods of time, but there may be
periods in which the price paid for crude oil purchased under those agreements
may be higher or lower than the price that might have been paid in the spot
market. Internal estimates indicate that the pricing mechanism is working as
intended to reflect market prices over long periods of time.
These crude supply agreements contain force majeure provisions which excuse
the performance by either party of its obligations under the agreement under
specified circumstances. As a result of Venezuela and other countries following
production quotas established by OPEC, PDVSA invoked the force majeure
provisions and reduced the volume of crude oil supplied under the contracts in
April 1998, in February 1999 through October 2000 and in February 2001 through
March 2003. In one instance PDVSA noted operational and technical problems as
the reason for the declaration. As a result of these declarations of force
majeure, we were required to obtain crude oil from alternative sources, which
resulted in increased volatility in our operating margins. In 2002, 2001 and
2000, the increased cost of crude oil purchased due to these declarations of
force majeure was $42 million, $6 million and $5 million, respectively. We were
notified that effective March 6, 2003, PDVSA ended its most recent declaration
of force majeure under the crude supply agreements.
The supply agreements provide that if the supplier does not supply us with
the volume of crude oil and feedstock required under that agreement and that
failure is not excused by force majeure, then the supplier must pay us the
deemed margin, in the case of the Lake Charles supply agreement, and the deemed
margin and the applicable fixed cost, in the case of the Corpus Christi supply
agreement, for the amount of crude oil and feedstock not supplied. During 2000,
2001 and 2002, PDVSA did not deliver the feedstock naphtha pursuant to certain
contracts and has made or will make contractually specified payments in lieu
thereof. PDVSA paid us approximately $2 million for naphtha not delivered under
the supply agreements during each of 2000 and 2001. We expect to receive
approximately $3 million from PDVSA for naphtha not delivered under the supply
agreements during 2002.
Refined product purchases. The marketing and sale of refined petroleum
products represents our revenue generating activity. The demand for those
products in our market areas exceeds the capacity of our refineries to produce
them so we purchase significant quantities of refined products from affiliated
and non-affiliated suppliers. We must have the right refined products in the
right locations and in the right quantities in order to satisfy customer supply
arrangements and market requirements. Thus, we purchase and sell refined
products of various grades in various locations from other suppliers. Sales of
refined products are reported as revenue upon transfer of title to the buyer.
Purchases of refined product are treated as acquisitions, a component of cost of
sales, upon transfer of title to us.
We are required to purchase refined products to supplement the production
of the Lake Charles, Corpus Christi and Lemont refineries in order to meet
demand of our marketing network and to resolve logistical issues. The following
table shows our purchases of refined products for the three years ended December
31, 2002.
50
CITGO REFINED PRODUCT PURCHASES
<Table>
<Caption>
YEAR ENDED
DECEMBER 31,
----------------------------------
2002 2001 2000
-------- -------- --------
(MBPD)
LIGHT FUELS
Gasoline ............ 689 640 616
Jet fuel ............ 61 74 81
Diesel/#2 fuel ...... 239 264 264
-------- -------- --------
Total ............... 989 978 961
======== ======== ========
</Table>
As of December 31, 2002, we purchased substantially all of the gasoline,
diesel/#2 fuel, and jet fuel produced at the LYONDELL-CITGO refinery under a
contract which extends through the year 2017. LYONDELL-CITGO was a major
supplier in 2002 providing us with 114 MBPD of gasoline, 84 MBPD of diesel/#2
fuel, and 18 MBPD of jet fuel. See "-- Refining --LYONDELL-CITGO Refining LP."
In October 1998, PDVSA V.I., Inc., an affiliate of PDVSA, acquired a 50%
equity interest in HOVENSA, a joint venture that owns and operates a refinery in
St. Croix, U.S. Virgin Islands. Under the related product sales agreement, we
acquired approximately 100 MBPD of refined products from the refinery during
2002, approximately one-half of which was gasoline.
MARKETING
Our major products are light fuels (including gasoline, jet fuel, and
diesel fuel), industrial products and petrochemicals, asphalt, lubricants and
waxes. The following table shows revenues and volumes of each of these product
categories for the three years ended December 31, 2002.
REFINED PRODUCT SALES REVENUES AND VOLUMES
<Table>
<Caption>
YEAR ENDED DECEMBER 31, YEAR ENDED DECEMBER 31,
------------------------------- -------------------------------
2002 2001 2000 2002 2001 2000
------- ------- ------- ------- ------- -------
(IN MILLIONS) (GALLONS IN MILLIONS)
LIGHT FUELS
Gasoline ................................ $11,758 $11,316 $12,447 15,026 13,585 13,648
Jet fuel ................................ 1,402 1,660 2,065 2,003 2,190 2,367
Diesel/#2 fuel .......................... 3,462 3,984 4,750 5,031 5,429 5,565
ASPHALT ................................... 597 502 546 902 946 812
PETROCHEMICALS AND INDUSTRIAL PRODUCTS .... 1,485 1,490 1,763 2,190 2,297 2,404
LUBRICANTS AND WAXES ...................... 561 536 552 261 240 279
------- ------- ------- ------- ------- -------
Total refined product sales ............. $19,265 $19,488 $22,123 25,413 24,867 25,075
======= ======= ======= ======= ======= =======
</Table>
Light Fuels. Gasoline sales accounted for 61% of our refined product sales
in 2002, 58% in 2001 and 56% in 2000. We market CITGO branded gasoline through
approximately 13,000 independently owned and operated CITGO branded retail
outlets located throughout the United States, primarily east of the Rocky
Mountains. We purchase gasoline to supply our marketing network, as the gasoline
production from the Lake Charles, Corpus Christi and Lemont refineries was only
equivalent to approximately 54%, 55% and 62% of the volume of our branded
gasoline sold in 2002, 2001 and 2000, respectively. See "-- Crude Oil and
Refined Product Purchases -- Refined Product Purchases."
The following table includes wholesale fuel sales.
<Table>
<Caption>
YEAR ENDED DECEMBER 31,
----------------------------
2002 2001 2000
------ ------ ------
(GALLONS IN MILLIONS)
Wholesale fuel sales 13,758 13,500 13,441
</Table>
Our strategy is to enhance the value of the CITGO brand by delivering
quality products and services to the consumer through a large network of
independently owned and operated CITGO branded retail locations. This
enhancement is accomplished through a commitment to quality, dependability and
excellent customer service to our independent marketers, which constitute our
primary distribution channel.
51
Sales to independent branded marketers typically are made under contracts
that range from three to seven years. Sales to 7-Eleven(TM) convenience stores
are made under a contract that extends through the year 2006. Under this
contract, we arrange all transportation and delivery of motor fuels and handle
all product ordering. We also act as processing agent for the purpose of
facilitating and implementing orders and purchases from third-party suppliers.
We receive a processing fee for such services.
We market jet fuel directly to airline customers at 20 airports, including
such major hub cities as Atlanta, Chicago, Dallas/Fort Worth and Miami.
Our delivery of light fuels to our customers is accomplished in part
through 55 refined product terminals located throughout our primary market
territory. Of these terminals, 44 are wholly-owned by us and 11 are jointly
owned. Twelve of our product terminals have waterborne docking facilities, which
greatly enhance the flexibility of our logistical system. Refined product
terminals owned or operated by us provide a total storage capacity of
approximately 22 million barrels. Also, we have active exchange relationships
with over 300 other refined product terminals, providing flexibility and timely
response capability to meet distribution needs.
Petrochemicals and Industrial Products. We sell petrochemicals in bulk to a
variety of U.S. manufacturers as raw material for finished goods. The majority
of our cumene production is sold to Mount Vernon Phenol Plant Partnership, a
joint venture phenol production plant in which we are a partner. The phenol
plant produces phenol and acetone for sale primarily to the principal partner in
the phenol plant for the production of plastics. Sulfur is sold to the U.S. and
international fertilizer industries; cycle oils are sold for feedstock
processing and blending; natural gas liquids are sold to the U.S. fuel and
petrochemical industry; petroleum coke is sold primarily in international
markets, through TCP Petcoke Corporation, a joint venture, for use as kiln and
boiler fuel; and residual fuel blendstocks are sold to a variety of fuel oil
blenders.
Asphalt. Our asphalt is generally marketed to independent paving
contractors on the East and Gulf Coasts and in the Midwest of the United States
for use in the construction and resurfacing of roadways. We deliver asphalt
through three wholly-owned terminals and twenty-three leased terminals. Demand
for asphalt peaks in the summer months.
Lubricants and Waxes. We market many different types, grades and container
sizes of lubricants and wax products, with the bulk of sales consisting of
automotive oil and lubricants and industrial lubricants. Other major lubricant
products include 2-cycle engine oil and automatic transmission fluid.
INTERNATIONAL OPERATIONS
We, through our wholly-owned subsidiary, CITGO International Latin America,
Inc. ("CILA"), are introducing the PDVSA and CITGO brands into various Latin
American markets which will include wholesale and retail sales of lubricants,
gasoline and distillates. Operations are in Puerto Rico, Mexico, Ecuador, Chile,
and Brazil. However, CILA is reviewing and may revise its plans for these and
other countries in Latin America.
PIPELINE OPERATIONS
We own and operate a crude oil pipeline and three products pipeline
systems. We also have equity interests in three crude oil pipeline companies and
six refined product pipeline companies. Our pipeline interests provide us with
access to substantial refinery feedstocks and reliable transportation to refined
product markets, as well as cash flows from dividends. One of the refined
product pipelines in which we have an interest, Colonial Pipeline, is the
largest refined product pipeline in the United States, transporting refined
products from the Gulf Coast to the mid-Atlantic and eastern seaboard states. We
have a 15.8 percent ownership interest in Colonial Pipeline.
EMPLOYEES
We and our subsidiaries have a total of approximately 4,300 employees,
approximately 1,500 of whom are covered by union contracts. Most of the union
employees are employed in refining operations. The remaining union employees are
located primarily at a lubricant plant and various refined product terminals.
ENVIRONMENT AND SAFETY
ENVIRONMENT
We are subject to the federal Clean Air Act ("CAA") which includes the New
Source Review ("NSR") program as well as the Title V air permitting program; the
federal Clean Water Act which includes the National Pollution Discharge
Elimination System program; the Toxic Substances Control Act; and the federal
Resource Conservation and Recovery Act and their equivalent state
52
programs. We are required to obtain permits under all of these programs and have
approximately 1,000 permits. These permits have terms which vary from one to ten
years after which they are subject to renewal. We believe we are in compliance
with the terms of these permits. We do not have any material Comprehensive
Environmental Response, Compensation, and Liability Act ("CERCLA") liability
because the former owners of many of our assets have by explicit contractual
language assumed all or the material portion of CERCLA obligations related to
those assets. This includes the Lake Charles refinery and the Lemont refinery.
The U.S. refining industry is required to comply with increasingly
stringent product specifications under the 1990 Clean Air Act Amendments for
reformulated gasoline and low sulfur gasoline and diesel fuel that have
necessitated additional capital and operating expenditures, and altered
significantly the U.S. refining industry and the return realized on refinery
investments. Also, regulatory interpretations by the U.S. EPA regarding the term
"modifications" to refinery equipment under the New Source Review ("NSR")
provisions of the Clean Air Act have created uncertainty about the extent to
which additional capital and operating expenditures will be required and
administrative penalties imposed.
Federal, state and local environmental laws and regulations may require us
to take additional compliance actions and also actions to remediate the effects
on the environment of prior disposal or release of petroleum, hazardous
substances and other waste and/or pay for natural resource damages. Maintaining
compliance with environmental laws and regulations could require significant
capital expenditures and additional operating costs. Also, numerous other
factors affect our plans with respect to environmental compliance and related
expenditures. See "Forward Looking Statements."
Our accounting policy establishes environmental reserves as probable site
restoration and remediation obligations become reasonably capable of estimation.
We believe the amounts provided in our consolidated financial statements, as
prescribed by generally accepted accounting principles, are adequate in light of
probable and estimable liabilities and obligations. However, we cannot assure
that the actual amounts required to discharge alleged liabilities and
obligations and to comply with applicable laws and regulations will not exceed
amounts provided for or will not have a material adverse affect on our
consolidated results of operations, financial condition and cash flows.
In 1992, we reached an agreement with the Louisiana Department of
Environmental Quality ("LDEQ"), to cease usage of certain surface impoundments
at our Lake Charles refinery by 1994. A mutually acceptable closure plan was
filed with the LDEQ in 1993. We and the former owner of the refinery are
participating in the closure and sharing the related costs based on estimated
contributions of waste and ownership periods. The remediation commenced in
December 1993. In 1997, we presented a proposal to the LDEQ revising the 1993
closure plan. In 1998 and 2000, we submitted further revisions as requested by
the LDEQ. The LDEQ issued an administrative order in June 2002 that addressed
the requirements and schedule for proceeding to develop and implement the
corrective action or closure plan for these surface impoundments and related
waste units. Compliance with the terms of the administrative order has begun. We
have incurred remediation costs to date related to these surface impoundments of
approximately $45 million. Based on currently available information and proposed
remedial approach, we currently anticipate closure and post -closure costs
related to these surface impoundments and related solid waste management units
to range from $36 million to $41 million.
We and the Texas Commission on Environmental Quality ("TCEQ") have had
preliminary discussions in which it was agreed that we and the TCEQ will begin
settlement negotiations intended to resolve all outstanding enforcement issues
between us and the TCEQ related to the Corpus Christi Refinery. It is
contemplated that this settlement will include, among other issues, all
outstanding issues associated with the notice of enforcement arising from the
2002 multi-media investigation of the Corpus Christi refinery as well as the
proposed penalties for failure to maintain equipment upset records, to obtain
authority for certain sulfur dioxide and hydrogen sulfide emissions and to
comply with certain air limitations at the Corpus Christi refinery during 2000
and 2001. We do not believe that the resolution of these enforcement matters
will have a material adverse effect on our consolidated results of operations,
financial condition and cash flows.
In June 1999, we and numerous other industrial companies received notice
from the U.S. EPA that the U.S. EPA believes that we and these other companies
have contributed to contamination in the Calcasieu Estuary, in the proximity of
Lake Charles, Calcasieu Parish, Louisiana and are Potentially Responsible
Parties ("PRPs") under CERCLA. The U.S. EPA made a demand for payment of its
past investigation costs from us and other PRPs and since 1999 has been
conducting a Remedial Investigation/Feasibility Study ("RI/FS") under its CERCLA
authority. The U.S. EPA released the draft of the remedial investigation phase
of the report in May 2003. We and other PRPs may be potentially responsible for
the costs of the RI/FS, subsequent remedial actions and natural resource
damages. Although we are still reviewing the recent remedial investigation phase
of the report and its implications, we submitted initial comments on the report
in July 2003. Also the EPA and the LDEQ issued a memorandum of understanding in
June 2003 assigning the primary areas of responsibility between the agencies
related to the Calcasieu Estuary. While we disagree with many of the U.S. EPA's
earlier allegations and conclusions, we are in discussions with the LDEQ on
issues relative to our operations adjacent to the Bayou D'Inde tributary section
of the Calcasieu Estuary and separately on issues relative to our refinery
operations on other sections of the Estuary. If necessary, we still intend to
contest this matter.
53
In January and July 2001, we received notices of violation ("NOVs") from
the U.S. EPA alleging violations of the Federal Clean Air Act. The NOVs are an
outgrowth of an industry-wide and multi-industry U.S. EPA enforcement initiative
alleging that many refineries and electric utilities modified air emission
sources without obtaining permits or installing new control equipment under the
NSR provisions of the Clean Air Act. The NOVs followed inspections and formal
information requests regarding our Lake Charles, Louisiana, Corpus Christi,
Texas and the Lemont, Illinois refineries. Since mid-2002, we have been engaged
in global settlement negotiations with the United States. The settlement
negotiations have focused on different levels of air pollutant emission
reductions and the merits of various types of control equipment to achieve those
reductions. No settlement agreement, or agreement in principle, has been
reached. Based primarily on the costs of control equipment reported by the
United States and other petroleum companies and the types and number of emission
control devices that have been agreed to in previous petroleum companies' NSR
settlements with the United States, we estimate that the capital costs of a
settlement with the United States could range from $130 million to $200 million.
Any such capital costs would be incurred over a period of years, anticipated to
be from 2003 to 2008. Also, this cost estimate range, while based on current
information and judgment, is dependent on a number of subjective factors,
including the types of control devices installed, the emission limitations set
for the units, the year the technology may be installed, and possible future
operational changes. We also may be subject to possible penalties. If settlement
discussions fail, we are prepared to contest the NOVs. If we are found to have
violated the provisions cited in the NOVs, we estimate the capital expenditures
and penalties that might result could range up to $290 million, to be incurred
over a period of years.
In June 1999, an NOV was issued by the U.S. EPA alleging violations of the
National Emission Standards for Hazardous Air Pollutants regulations covering
benzene emissions from wastewater treatment operations at our Lemont, Illinois
refinery. We are in settlement discussions with the U.S. EPA. We believe this
matter will be consolidated with the matters described in the previous
paragraph.
In June 2002, a Consolidated Compliance Order and Notice of Potential
Penalty was issued by the LDEQ alleging various violations of the Louisiana air
quality regulations at the Lake Charles, Louisiana refinery. We are in
settlement discussions with the LDEQ.
Various regulatory authorities have the right to conduct, and from time to
time do conduct, environmental compliance audits of our and our subsidiaries'
facilities and operations. Those audits have the potential to reveal matters
that those authorities believe represent non-compliance in one or more respects
with regulatory requirements and for which those authorities may seek corrective
actions and/or penalties in an administrative or judicial proceeding. Based upon
current information, we are not aware that any such audits or their findings
have resulted in the filing of such a proceeding or is the subject of a
threatened filing with respect to such a proceeding, nor do we believe that any
such audit or their findings will have a material adverse effect on our future
business and operating results, other than matters described above.
Conditions which require additional expenditures may exist with respect to
our various sites including, but not limited to, our operating refinery
complexes, former refinery sites, service stations and crude oil and petroleum
product storage terminals. Based on currently available information, we cannot
determine the amount of any such future expenditures.
Increasingly stringent environmental regulatory provisions and obligations
periodically require additional capital expenditures. During 2002, we spent
approximately $148 million for environmental and regulatory capital improvements
in our operations. Management currently estimates that we will spend
approximately $1.3 billion for environmental and regulatory capital projects
over the five-year period 2003-2007.
<Table>
<Caption>
2003 2004 2005 2006 2007
------ ------ ------ ------ ------
(IN MILLIONS)
Tier 2 gasoline(1) ................ $ 231 $ 125 $ 82 $ 10 $ --
Ultra low sulfur diesel(2) ........ 3 33 179 155 175
Other environmental(3) ............ 35 51 81 92 54
------ ------ ------ ------ ------
Total regulatory/environmental .... $ 269 $ 209 $ 342 $ 257 $ 229
====== ====== ====== ====== ======
</Table>
- ----------
(1) In February 2000, the EPA promulgated the Tier 2 Motor Vehicle Emission
Standards Final Rule for all passenger vehicles, establishing standards
for sulfur content in gasoline. These regulations mandate that the
average sulfur content of gasoline for highway use produced at any
refinery not exceed 30 parts per million during any calendar year by
January 1, 2006, with a phase-in beginning January 1, 2004. In order to
comply with these regulations, CITGO will install additional
hydroprocessing facilities at its refineries. (Hydroprocessing
facilities remove sulfur from oil by means of a chemical reaction which
occurs when the oil is mixed with hydrogen, heated and processed over a
catalyst.)
54
(2) Spending on Ultra Low Sulfur Diesel ("ULSD") assumes the EPA will
require ULSD for on-road diesel in 2006 and ULSD for off-road diesel
use in 2008. The ULSD program will require CITGO to make additional
capital investments at its refineries. The estimates shown here are
based on the installation of traditional hydroprocessing facilities.
These regulations are not final and spending could be reduced if
certain alternative regulatory schemes proposed by EPA are adopted.
CITGO continues to evaluate new technological innovations which may
reduce the required investment.
(3) Other environmental spending assumes $162.9 million in spending to
comply with New Source Review standards under the Clean Air Act.
These estimates may vary due to a variety of factors. See "Management's
Discussion and Analysis of Financial Condition and Results of Operations --
Liquidity and Capital Resources" and "Forward Looking Statements."
SAFETY
Due to the nature of petroleum refining and distribution, we are subject to
stringent federal and state occupational health and safety laws and regulations.
We maintain comprehensive safety, training and maintenance programs.
LEGAL PROCEEDINGS
Various lawsuits and claims arising in the ordinary course of business are
pending against us. We record accruals for potential losses when, in
management's opinion, such losses are probable and reasonably estimable. If
known lawsuits and claims were to be determined in a manner adverse to us, and
in amounts greater than our accruals, then such determinations could have a
material adverse effect on our results of operations in a given reporting
period. The most significant lawsuits and claims are discussed below.
The electricity supplier to the Lemont, Illinois refinery is seeking
recovery from us of alleged underpayments for electricity in a proceeding before
the Illinois Commerce Commission. We made a motion for summary judgment before
the administrative law judge in this matter. Of the four issues before the
judge, the judge ruled in our favor in three of the four issues, and ruled that
the electric supplier was not the proper party in interest with regard to the
final issue. Unless the electric supplier elects to appeal this decision, this
matter should now be concluded.
In September 2002, a Texas court ordered us to pay property owners and
their attorneys approximately $6 million based on an alleged settlement of class
action property damage claims as a result of alleged air, soil and groundwater
contamination from emissions released from our Corpus Christi, Texas refinery.
We have appealed the ruling to the Texas Court of Appeals.
We are one of several refinery defendants to state and federal lawsuits in
New York and state actions in Illinois and California alleging contamination of
water supplies by MTBE, a component of gasoline. The plaintiffs claim that MTBE
is a defective product and that refiners failed to adequately warn customers and
the public about risks associated with the use of MTBE in gasoline. These
actions allege that MTBE poses public health risks and seek testing, damages and
remediation of the alleged contamination. The plaintiffs filed putative class
action lawsuits in federal courts in Illinois, California, Florida and New York.
We were named as a defendant in all but the California case. The federal cases
were all consolidated in a Multidistrict Litigation case in the United States
District Court for the Southern District of New York ("MDL"). In July 2002, the
court in the MDL case denied plaintiffs' motion for class certification. The
California plaintiffs in the MDL action then dismissed their federal lawsuit and
refiled in state court in California. Subsequently, the remaining MDL plaintiffs
settled with us and our codefendants for an amount that did not have a material
impact on our financial condition or results of operations. We anticipate a
similar settlement of the California lawsuit. In August 2002, a New York state
court judge handling two separate but related individual MTBE lawsuits dismissed
plaintiffs' product liability claims, leaving only traditional nuisance and
trespass claims for leakage from underground storage tanks at gasoline stations
near plaintiffs' water wells. Subsequently, a putative class action involving
the same leaking underground storage tanks has been filed. We have filed a
motion to dismiss the case and will also oppose class certification. Also, in
late October 2002, the County of Suffolk, New York, and the Suffolk County Water
Authority filed suit in state court, claiming MTBE contamination of that
county's water supply. The Illinois state action has been brought on behalf of a
class of contaminated well owners in Illinois and a second class of all well
owners within a defined distance of leaking underground storage tanks. The judge
in the Illinois state court action is expected to hear plaintiffs' motion for
class certification in that case sometime within the next year. On July 20,
2001, the Village of East Alton, Illinois, sued Union Oil Company of California
("Unocal") and other defendants in Illinois state court for alleged MTBE
contamination of its public water supply. Plaintiff, in the original complaint
and two subsequent amendments, has asserted claims of strict liability,
negligence, trespass and nuisance, and seeks compensatory damages and
declaratory judgment that defendants are liable for the full cost of
remediation. Unocal tendered the defense of the case to PDVMR pursuant to a
Partnership Interest Retirement Agreement among the Uno-Ven Company, PDV
America, PDVMR, Unocal, Midwest 76, Inc., and Lemont Carbon, Inc., dated April
11, 1997. PDVMR is our subsidiary and has accepted the tender of defense with a
reservation of rights. Unocal has answered the most recent amended complaint and
discovery has commenced. The case is expected to be mediated in late summer or
early fall of 2003.
55
In August 1999, the U.S. Department of Commerce rejected a petition filed
by a group of independent oil producers to apply antidumping measures and
countervailing duties against imports of crude oil from Venezuela, Iraq, Mexico
and Saudi Arabia. The petitioners appealed this decision before the U.S. Court
of International Trade based in New York. On September 19, 2000, the Court of
International Trade remanded the case to the Department of Commerce with
instructions to reconsider its August 1999 decision. The Department of Commerce
was required to make a revised decision as to whether or not to initiate an
investigation within 60 days. The Department of Commerce appealed to the U.S.
Court of Appeals for the Federal Circuit, which dismissed the appeal as
premature on July 31, 2001. The Department of Commerce issued its revised
decision, which again rejected the petition, in August 2001. The revised
decision was affirmed by the Court of International Trade on December 17, 2002.
In February 2003, the independent oil producers appealed the decision of the
Court of International Trade.
We have been named as a defendant in approximately 125 asbestos lawsuits
pending in state and federal courts, primarily in Louisiana, Texas and Illinois.
These cases, most of which involve multiple defendants, are brought by former
employees or contractor employees seeking damages for asbestos related illnesses
allegedly caused, at least in part, from exposure at refineries owned or
operated by us in Lake Charles, Louisiana, Corpus Christi, Texas and Lemont,
Illinois. In many of these cases, the plaintiffs' alleged exposure occurred over
a period of years extending back to a time before we owned or operated the
premises at issue. In some of these cases, we are indemnified by or have the
right to seek indemnification for losses and expenses that we may incur from
prior owners of the refineries or employers of the claimants. In other cases,
our involvement arises not from having been sued directly but because prior
owners of our refineries have asserted indemnification rights against us. We do
not believe that the resolution of these cases will have a material adverse
effect on our financial condition or results of operations.
56
MANAGEMENT
The following table sets forth the names and titles of our board of
directors and executive officers:
<Table>
<Caption>
Name Age Position
- --------------------------------- --- -------------------------------------
Luis E. Marin.................... 45 President, Chief Executive Officer
and Director
Antonio J. Rivero................ 40 Executive Vice President and Director
Eddie R. Humphrey................ 54 Senior Vice President and Chief
Financial and Administration Officer
Jerry E. Thompson................ 53 Senior Vice President and Chief
Operating Officer
Peer L. Anderson................. 58 Vice President and General Counsel
Robert E. Funk................... 58 Vice President, Corporate Planning &
Economics
Alvin W. Prebula................. 56 Vice President, Lake Charles
Manufacturing Complex
Robert J. Kostelnik.............. 51 Vice President, Health, Safety,
Security of Assets and Environmental
Protection
Fernando J. Garay................ 41 Corporate Secretary
Terry Charles.................... 57 General Auditor and Principal
Auditing Officer
Larry Krieg...................... 53 Controller and Chief Accounting
Officer
Aires Barreto.................... 58 Chairman, Board of Directors
Nelson Martinez.................. 52 Director
William Padron................... 46 Director
Dester Rodriguez................. 41 Director
Luis Vierma...................... 50 Director
</Table>
OUR EXECUTIVE OFFICERS
LUIS E. MARIN
PRESIDENT AND CHIEF EXECUTIVE OFFICER AND DIRECTOR
Luis Marin has served as our director since May 2003, and he is also a
member of the PDVSA board of directors. In August 2003 he became President and
Chief Executive Officer of CITGO. Mr. Marin graduated as a natural gas engineer
from the University of Oklahoma in 1980. He completed postgraduate studies in
oil management at Oxford Petroleum College in England in 1987, and in management
at the Massachusetts Institute of Technology (MIT) in 1997. He joined PDVSA in
1980 and has held several positions in Natural Gas Planning; General
Engineering; Gas Operations; Petroleum Engineering; Production, Trade and Supply
Operations; and Technical Management. He has been an advisor to the General
Manager of Production and a Coordinator of Exploration Projects.
In 2000, he became Manager of Drilling in Eastern Venezuela. Later, he
became Manager of the Ceuta-Tomoporo Development Project and in 2002 was
appointed Manager of Corporate Production Planning. Subsequently, he was
appointed Deputy Production Manager of the Eastern Venezuela Division.
ANTONIO J. RIVERO
EXECUTIVE VICE PRESIDENT AND DIRECTOR
Antonio Rivero was named Executive Vice President of CITGO in August 2003
and he also serves on CITGO's board of directors. In February 2003, he was named
General Manager of PDVSA Services, Inc., located in Houston, Texas. Prior to
that time, he held several positions at CITGO's headquarters, including Senior
Derivatives Trader and Senior Financial Consultant. He was also assigned by
executive management to special projects, including the PDVSA Commission for the
International Investment Assessment and the PDVSA Internationalization Study.
Mr. Rivero graduated from the Military Academy of Venezuela in 1983 with a
bachelors degree in military sciences. He served as a Venezuelan Army Officer
until 1994. From 1994 to 1998, he was President and CEO of R&C Electronic
Corporation, a Venezuelan information, technology and telecommunications
company.
EDDIE R. HUMPHREY
SENIOR VICE PRESIDENT AND CHIEF FINANCIAL AND ADMINISTRATION OFFICER
Eddie Humphrey joined CITGO in 1978. From May 1992 to May 2001, he served
as CITGO's Treasurer. From May 2001 to August 2002, he served as CITGO's Vice
President and Chief Financial Officer. Since August 2002, he has served as
Senior Vice President and Chief Financial Officer. He is responsible for the
Corporate Controllers group, Bank Operations, Treasurers group, Human Resources,
Information Security, Information Technology, Health, Safety and Environmental
Excellence, Insurance and Risk, Budgets and Performance Analysis, Tax and
Administrative Services. Mr. Humphrey previously served as the Company's
Treasurer
57
and Corporate Controller. Prior to joining CITGO, Mr. Humphrey received his
bachelors degree in Finance from Oklahoma State University, and he holds a
masters of business administration from the University of Tulsa.
JERRY E. THOMPSON
SENIOR VICE PRESIDENT AND CHIEF OPERATING OFFICER
Jerry Thompson joined CITGO in 1971. He became Vice President of Refining
for CITGO in 1987, Vice President of Corporate Planning & Economics in 1994,
Vice President Supply and Logistics in 1995, Vice President, Development &
Technological Excellence in 1998, and in 1999 was named a Senior Vice President.
From January 2002 through March 2002 he served as Senior Vice President of
Supply and Distribution and in April 2003 he was named Chief Operating Officer.
He is responsible for the supply, refining, trading and distribution of all
crude, intermediate feedstocks and refined products for the Asphalt, Light Oils,
Lubes and Petrochemicals business units. In addition, Mr. Thompson is
responsible for CITGO's Centers of Excellence. He also chairs the Short Term
Operating Committee. He is a graduate of Colorado School of Mines with a degree
in chemical and petroleum refining engineering. He began his career at the Lake
Charles, Louisiana, refinery as a process engineer and advanced through several
technical and operations supervisory and management positions.
PEER L. ANDERSON
VICE PRESIDENT AND GENERAL COUNSEL
Peer L. Anderson joined CITGO in September 1986 and has served as Vice
President and General Counsel since then. His responsibilities include
supervising the legal department. He holds a bachelor of arts degree and a juris
doctorate from the University of Oklahoma and a master of laws degree from
George Washington University.
He previously served as Director, Corporate Legal Services for Reading &
Bates Corporation from 1977 to 1986, as an attorney with Cities Service Company
from 1973 to 1977 and with the U.S. Army Judge Advocate General's Corps from
1969 to 1973.
ROBERT E. FUNK
VICE PRESIDENT, CORPORATE PLANNING & ECONOMICS
Bob Funk joined CITGO in 1968. He has served in various staff and technical
positions at the Lake Charles Manufacturing Complex and the Tulsa headquarters.
Since the formation of CITGO Petroleum Corporation in 1983, he has served as
General Manager Lube Operations, General Manager Facilities Planning and General
Manager Business Planning and Economics. Since November 1996 he has served as
our Vice President, Corporate Planning & Economics. He is responsible for all
budgeting and planning activities for the company including preparation of
annual operating and capital budgets, the Long Range Plan and Corporate
Performance Measures. He holds a bachelor of science degree in chemical
engineering from the University of Kansas.
ALVIN W. PREBULA
VICE PRESIDENT, LAKE CHARLES MANUFACTURING COMPLEX
Al Prebula joined CITGO in 1992 as General Manager Technical Services at
the Corpus Christi Refinery. He was named Vice President Corpus Christi Refinery
in March of 1996 and continued in that position until 1999, when he was named
Vice President of the Lake Charles Manufacturing Complex.
He was previously employed with Exxon Company, USA for 24 years where he
held various management positions, including Bayonne, N.J. Plant Manager. Mr.
Prebula holds a bachelor of science degree in mechanical engineering from the
University of Maryland and a masters of business administration degree from
Rutgers University.
ROBERT J. KOSTELNIK
VICE PRESIDENT, HEALTH, SAFETY, SECURITY OF ASSETS AND ENVIRONMENTAL PROTECTION
Bob Kostelnik, joined CITGO in 1992. Since October 2002 he has served as
CITGO's Vice President, Health, Safety, Security of Assets and Environmental
Protection. He is responsible for overseeing CITGO's health and safety
activities as well as asset security and environmental protection. Prior to
being named to his current position, Mr. Kostelnik was Vice President and
General Manager of CITGO's Corpus Christi refinery. He is a graduate of the
University of Missouri at Rolla with a bachelor of science in mechanical
engineering.
He has served as General Manager Operations at the Lake Charles
Manufacturing Complex, with operations and maintenance responsibility for the
Lake Charles Refinery and the CITGO lubricants and wax plant. He has ten years
of service at CITGO and a total of almost 30 years in the refining industry.
58
FERNANDO J. GARAY
CORPORATE SECRETARY
Fernando Garay came to CITGO in February 2002 as the International
Strategic Communications Developer within Government & Public Affairs. Prior to
joining CITGO, Mr. Garay served 8 years at the Secretariat of OPEC in Vienna,
Austria, where he was Editor of the OPEC News Agency and a spokesman for the
organization. While at OPEC, he also served as Press Director of the II Summit
of OPEC Heads of State and Government, held in Caracas in September 2000.
His experience includes a variety of positions with Reuters News Agency and
several Caracas-based publications, including El Nacional and The Daily Journal
newspapers. Mr. Garay graduated from the Central University of Venezuela in 1987
with a bachelors degree in communications. He also holds a master of arts in law
and diplomacy from Tufts University in Massachusetts.
TERRY CHARLES
GENERAL AUDITOR AND PRINCIPAL AUDITING OFFICER
Terry Charles serves as the General Auditor and Principal Auditing Officer
of CITGO. He has the responsibility of directing a continuous and comprehensive
program of audits of CITGO to evaluate its operating, administrative and
financial controls and to test the adequacy of its operating and accounting
systems.
Prior to his CITGO career, he was the General Manager of Discontinued
Operations for Cities Service Company, and he was involved in the original
creation of CITGO, and instrumental in the negotiations and sale of CITGO to The
Southland Corporation. Upon the sale in 1983, he became the Corporate Controller
and Chief Accounting Officer for CITGO and remained so until being appointed the
General Auditor in September 1988.
Mr. Charles graduated from Oklahoma State University with a bachelors
degree in accounting. After graduating, he began his business career with Arthur
Young & Company, Certified Public Accountants, in Tulsa. After approximately one
year with Arthur Young, he took a leave of absence and spent almost 5 years in
the United States Navy as a Naval Flight Officer, returning for several more
years at Arthur Young before beginning his career with CITGO/Cities Service. He
has been with CITGO/Cities Service for 29 years.
LARRY KRIEG
CONTROLLER AND CHIEF ACCOUNTING OFFICER
Larry Krieg joined CITGO in 1984. Since June 2001 he has served as
Controller and Chief Accounting Officer. He is responsible for all corporate
accounting functions including business unit accounting support as well as
internal and external financial reporting. Mr. Krieg previously served as
manager of accounting functions in supply and logistics, Lake Charles refinery
operations and lubricant operations. He has also served as Manager, Internal
Audit. Mr. Krieg received his bachelors degree in accounting from Oklahoma State
University. He is a Certified Public Accountant and Certified Internal Auditor.
OUR BOARD OF DIRECTORS
In addition to Mr. Marin, who is our President and Chief Executive Officer,
and Mr. Rivero, who is our Executive Vice President, the following people serve
on our board of directors:
AIRES BARRETO
Aires Barreto has served as our director and as Chairman of our board of
directors since January 2003. He previously served as our director from February
1999 to April 2001.
He received a masters degree in hydrocarbons economics and administration
from Loughborough University, England in 1968. Mr. Barreto is a chemical
engineer who graduated from the Instituto Quimico Sarria, Spain in 1966 and
received a bachelors degree in chemistry from the University of Bombay, India in
1963. He joined Compania Shell de Venezuela in 1974, where he held several
technical and supervisory positions, mainly at the Cardon refinery.
Since September 1982 Mr. Barreto has served in various positions with PDVSA
including Refining Planning Manager at the Maraven refinery, Manufacturing
Manager at the Cardon refinery, Planning Manager of Intevep, General Manager
Refining, Petrochemicals, and Technology of Intevep, Manufacture Planning
Manager, Corporate Topics Manager, Director of Pequiven and PDVSA Vice
President.
59
NELSON MARTINEZ
Nelson Martinez currently serves as a member of the PDVSA board of
directors and he became a director of CITGO in August 2003. He is an
award-winning chemist with more than 20 international patents. He holds a
bachelors degree in chemistry and a masters degree in physical chemistry from
the University of Poitiers in France. Mr. Martinez also received a master's in
technology management from the Massachusetts Institute of Technology and a
doctorate in chemistry from the University of Reading (United Kingdom). In 1994,
he was elected as a member of the New York Academy of Sciences for his
contributions to the study of catalysts in hydro treatment and catalytic
cracking.
Mr. Martinez joined Intevep, PDVSA's research and development subsidiary,
in 1980. At Intevep, he gained significant experience in the development of
catalytic supports and process technology, including managing the processes
development department. In 1987, he was appointed head of the catalysis section
for Intevep. In 1995, Mr. Martinez was named leader of the technology management
corporate group and manager of the PDVSA-Intevep planning function. From March
2000 to December 2002 he held the position of Deputy Manager of the refining and
petrochemicals general division. During this time, he also served as team
manager of new business developments. Prior to his appointment as a PDVSA
director, Mr. Martinez served as Refining Managing Director of PDVSA Oriente.
WILLIAM PADRON
William Padron has served as our director since January 2003. He holds a
degree in chemical engineering from Villanova University in Pennsylvania. He
began his career in the oil industry in 1979 at Lagoven, S.A., where he occupied
several technical and management positions.
After transferring from Lagoven, S.A. in 1988, Mr. Padron held various
positions at PDVSA affiliates, PDVSA's Corporate Center and PDVSA's Office of
the President, including assignments in human resources, supply, finance,
strategic and corporate planning, and corporate topics. Since 2001, Mr. Padron
has served as Deputy General Manager of Operadora Cerro Negro, S.A., in charge
of PDVSA and other joint venture participants' assets used for the production
and upgrading of Venezuelan extra heavy crude oil from the Orinoco tar belt.
DESTER RODRIGUEZ
Dester Rodriguez currently serves as a member of the PDVSA Board of
Directors and is a Venezuelan Army Colonel. Rodriguez graduated from the
Venezuelan Military Academy with a bachelors degree in military arts and
sciences and also obtained a degree in systems engineering from the Venezuelan
Armed Forces Experimental University.
In 1997, he was appointed head of personnel at the Army's Military
Engineering School. In 1998, he was appointed head of the Army Personnel
Registry and Control Division, a position he held until 1999, when he became
General Director of the Information Technology Office at the Ministry of
Education, Culture and Sports. During this time, Rodriguez also served as
president of the Bolivarian Foundation of Information Sciences.
Rodriguez was appointed to the PDVSA restructuring committee in December
2002 and to the PDVSA Board of Directors in March 2003 and he became a director
of CITGO in August 2003.
LUIS VIERMA
Luis Vierma is a member of the PDVSA board of directors and has served as
Vice-minister of Hydrocarbons at the Energy and Mines Ministry since 2002. He
holds a bachelors degree in chemistry from the Central University of Venezuela
(1978) and a masters degree in geology from Indiana University (1984). He joined
PDVSA as an exploration chemist in 1978 and held that position until 1981, when
he started his graduate studies at Indiana University. Upon his return to
Venezuela, he was named Director of the Geochemistry Laboratory of PDVSA's
Exploration Center, and Leader of Hydrocarbon Exploration Projects.
Subsequently, he was appointed director of the Inorganic Geochemistry Unit.
In 1993, he became Assistant Manager under an agreement between the
Venezuelan Energy and Mines Ministry and the U.S. Department of Energy for the
improved recovery of micro-organic crude. In 1995, he was appointed head of the
Geochemistry Section of the PDVSA Exploration Center. Two years later, he was
named head of the Geology Section, and the following year, he became Exploration
Business Manager. In 2000, he was appointed Director of the Policy and Planning
Office for Hydrocarbons at the Energy and Mines Ministry. He has been a board
member of CITGO since May 2003.
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RELATED PARTY TRANSACTIONS
We have entered into several transactions with PDVSA or affiliates of
PDVSA, including crude oil and feedstock supply agreements, agreements for the
purchase of refined products and transportation agreements. Under these
agreements, we purchased approximately $3.3 billion of crude oil, feedstocks and
refined products at market related prices from PDVSA in 2002. At December 31,
2002, $262 million was included in our current payable to affiliates as a result
of its transactions with PDVSA. At December 31, 2002, we had approximately $90
million in accounts payable related to crude oil deliveries from PDVSA for which
we had not received invoices.
Most of the crude oil and feedstocks purchased by us from PDVSA are
delivered on tankers owned by PDV Marina, S.A., a wholly-owned subsidiary of
PDVSA. In 2002, 56% of the PDVSA contract crude oil delivered to the Lake
Charles and Corpus Christi refineries was delivered on tankers operated by this
PDVSA subsidiary.
LYONDELL-CITGO owns and operates a 265 MBPD refinery in Houston, Texas.
LYONDELL-CITGO was formed in 1993 by subsidiaries of us and Lyondell ("the
Owners"). The heavy crude oil processed by the Houston refinery is supplied by
PDVSA under a long-term crude oil supply agreement through the year 2017. Under
this agreement, LYONDELL-CITGO purchased approximately $1.3 billion of crude oil
and feedstocks at market related prices from PDVSA in 2002. We purchase
substantially all of the gasoline, diesel and jet fuel produced at the Houston
refinery under a long-term contract. (See consolidated financial statements of
CITGO, which are attached as an appendix to this prospectus). Various disputes
exist between LYONDELL-CITGO and the partners and their affiliates concerning
the interpretation of these and other agreements between the parties relating to
the operation of the refinery.
Our participation interest in LYONDELL-CITGO was approximately 41% at
December 31, 2002, in accordance with agreements between the Owners concerning
such interest. We held a note receivable from LYONDELL-CITGO of $35 million at
December 31, 2002. The note bears interest at market rates which were
approximately 2.4% at December 31, 2002, and is due in December 2004.
On December 11, 2002, LYONDELL-CITGO completed a refinancing of its working
capital revolver and its $450 million term bank loan. The new term loan and
working capital revolver will mature in June 2004.
We account for our investment in LYONDELL-CITGO using the equity method of
accounting and record our share of the net earnings of LYONDELL-CITGO based on
allocations of income agreed to by the Owners. Cash distributions are allocated
to the owners based on participation interest.
In October 1998, PDVSA V.I., Inc., an affiliate of PDVSA, acquired a 50%
equity interest in HOVENSA and has the right under a product sales agreement to
assign periodically to us, or other related parties, its option to purchase 50%
of the refined products produced by HOVENSA (less a certain portion of such
products that HOVENSA will market directly in the local and Caribbean markets).
In addition, under the product sales agreement, the PDVSA affiliate has
appointed us as its agent in designating which of its affiliates shall from time
to time take deliveries of the refined products available to it. The product
sales agreement will be in effect for the life of the joint venture, subject to
termination events based on default or mutual agreement (See consolidated
financial statements of CITGO, which are attached as an appendix to this
prospectus). Pursuant to the above arrangement, we acquired approximately 100
MBPD of refined products from the refinery during 2002, approximately one-half
of which was gasoline.
The refined product purchase agreements with LYONDELL-CITGO and HOVENSA
incorporate various formula prices based on published market prices and other
factors. Such purchases totaled $3.5 billion for 2002. At December 31, 2002,
$110 million was included in payables to affiliates as a result of these
transactions.
We had refined product, feedstock, crude oil and other product sales of
$277 million to affiliates, including LYONDELL-CITGO and Mount Vernon Phenol
Plant Partnership, in 2002. At December 31, 2002, $94 million was included in
due from affiliates as a result of these and related transactions.
We have guaranteed approximately $66 million of debt of certain affiliates,
including $10 million related to HOVENSA and $51 million related to PDV Texas,
Inc. (See consolidated financial statements of CITGO, which are attached as an
appendix to this prospectus.)
Under a separate guarantee of rent agreement, PDVSA has guaranteed payment
of rent, stipulated loss value and termination value due under the lease of the
Corpus Christi Refinery West Plant facilities. (See consolidated financial
statements of CITGO, which are attached as an appendix to this prospectus.)
In August 2002, three affiliates entered into agreements to advance excess
cash to us from time to time under demand notes for amounts of up to a maximum
of $10 million with PDV Texas, Inc., $30 million with PDV America and $10
million with PDV Holding. The notes bear interest at rates equivalent to 30-day
LIBOR plus 0.875% payable quarterly. Amounts outstanding on these
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notes at December 31, 2002 were $5 million, $30 million and $4 million from PDV
Texas, PDV America and PDV Holding, respectively, and are included in payables
to affiliates in our consolidated balance sheet. On February 27, 2003, we repaid
$5 million to PDV Texas, $20.5 million to PDV America and $4 million to PDV
Holding. At June 30, 2003, there was no outstanding balance on these notes.
We and PDV Holding are parties to a tax allocation agreement that is
designed to provide PDV Holding with sufficient cash to pay its consolidated
income tax liabilities. PDV Holding appointed us as its agent to handle the
payment of such liabilities on its behalf. As such, we calculate the taxes due,
allocate the payment among the members according to the agreement and bill each
member accordingly. Each member records its amounts due or payable to us in a
related party payable account. At December 31, 2002, we had net related party
receivables related to federal income taxes of $25 million.
THE EXCHANGE OFFER
The following is a summary of the exchange offer relating to the
outstanding notes. As a summary, it does not contain all of the information you
might find useful. For further information, you should read the registration
rights agreement and the form of letter of transmittal, copies of which have
been filed as exhibits to the registration statement. The exchange offer is
intended to satisfy certain of our obligations under the registration rights
agreement.
PURPOSE AND EFFECT OF THE EXCHANGE OFFER
EXCHANGE OFFER REGISTRATION STATEMENT. We sold the outstanding notes to
Credit Suisse First Boston LLC, J.P. Morgan Securities Inc., BNY Capital
Markets, Inc., SG Cowen Securities Corporation, SunTrust Capital Markets, Inc.,
Mizuho International plc and BNP Paribas Securities Corp., or the "initial
purchasers," on February 27, 2003. The initial purchasers have advised us that
they subsequently resold the outstanding notes to "qualified institutional
buyers" in reliance on Rule 144A under the Securities Act and to no-U.S. persons
in reliance on Regulation S under the Securities Act. As a condition to the
offerings of the outstanding notes, we entered into a registration rights
agreement dated February 27, 2003, pursuant to which we agreed, for the benefit
of all holders of the outstanding notes, at our own expense, to use our
reasonable best efforts to consummate the exchange offer within 220 days after
the initial issue date of the outstanding notes.
Further, we agreed to keep the exchange offer open for acceptance for not
less than 30 nor more than 40 days, such 40th day being the "Consummation
Deadline." For each outstanding note validly tendered pursuant to the exchange
offer and not withdrawn, the holder of that note will receive an exchange note
having a principal amount equal to that of the tendered outstanding note.
Interest on each exchange note will accrue from the last date on which interest
was paid on the tendered outstanding note in exchange therefor or, if no
interest was paid on that outstanding note, from the issue date.
TRANSFERABILITY. We issued the outstanding notes on February 27, 2003 in a
transaction exempt from the registration requirements of the Securities Act and
applicable state securities laws. Accordingly, the outstanding notes may not be
offered or sold in the United States unless registered or pursuant to an
applicable exemption under the Securities Act and applicable state securities
laws. Based on no-action letters issued by the staff of the SEC with respect to
similar transactions, we believe that the exchange notes issued pursuant to the
exchange offer in exchange for outstanding notes may be offered for resale,
resold and otherwise transferred by holders of notes who are not our affiliates
without further compliance with the registration and prospectus delivery
requirements of the Securities Act, provided that:
o any exchange notes to be received by the holder were acquired in the
ordinary course of the holder's business;
o at the time of the commencement of the exchange offer, the holder has
no arrangement or understanding with any person to participate in the
distribution, within the meaning of the Securities Act, of the
exchange notes;
o the holder is not an "affiliate" of ours, as defined in Rule 405 under
the Securities Act; and
o the holder did not purchase the outstanding notes directly from us to
resell pursuant to 144A or another available exemption.
However, we have not sought a no-action letter with respect to the exchange
offer and we cannot assure you that the staff of the SEC would make a similar
determination with respect to the exchange offer. Any holder who tenders its
outstanding notes in the exchange offer with any intention of participating in a
distribution of exchange notes (1) cannot rely on the interpretation by the
staff of the SEC, (2) will not be able to validly tender outstanding notes in
the exchange offer and (3) must comply with the registration and prospectus
delivery requirements of the Securities Act in connection with any secondary
resale transactions.
Each broker-dealer that receives exchange notes for its own account in
exchange for outstanding notes, where those notes were acquired by such broker
dealer as a result of market-making activities or other trading activities, must
acknowledge that it will deliver a prospectus in connection with any resale of
those exchange notes. See "Plan of Distribution."
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SHELF REGISTRATION STATEMENT. In the event that:
(1) applicable interpretations of the staff of the SEC do not permit us to
effect the exchange offer; or
(2) for any other reason we do not consummate the exchange offer within 220
days after the date of original issue of the outstanding notes; or
(3) an initial purchaser shall notify us following consummation of the
exchange offer that outstanding notes held by it are not eligible to be
exchanged for exchange notes in the exchange offer; or
(4) certain holders are prohibited by law or SEC policy from participating
in the exchange offer or may not resell the exchange notes acquired by them in
the exchange offer to the public without delivering a prospectus,
then, we will, subject to certain exceptions,
(1) promptly file a shelf registration statement with the SEC covering
resales of the outstanding notes or the exchange notes, as the case may be;
(2) (A) in the case of clause (1) above, use our reasonable best efforts to
cause the shelf registration statement to be declared effective under the
Securities Act on or prior to the 180th day after the date of original issue of
the outstanding notes and (B) in the case of clause (2), (3) or (4) above, use
our reasonable best efforts to cause the shelf registration statement to be
declared effective under the Securities Act on or prior to the 90th day after
the date on which the shelf registration statement is required to be filed; and
(3) keep the shelf registration statement effective until the earliest of
(A) the time when the notes covered by the shelf registration statement can be
sold pursuant to Rule 144 without any limitations under clauses (c), (e), (f)
and (h) of Rule 144, (B) two years from the date of original issue of the
outstanding notes and (C) the date on which all outstanding notes registered
thereunder are disposed of in accordance therewith.
We will, in the event a shelf registration statement is filed, among other
things, provide to each holder for whom the shelf registration statement was
filed copies of the prospectus that is a part of the shelf registration
statement, notify each such holder when the shelf registration statement has
become effective and take other actions as are required to permit unrestricted
resales of the outstanding notes or the exchange notes, as the case may be. A
holder selling outstanding notes or exchange notes pursuant to the shelf
registration statement generally will be required to be named as a selling
security holder in the related prospectus and to deliver a prospectus to
purchasers, will be subject to applicable civil liability provisions under the
Securities Act in connection with sales of that kind and will be bound by the
provisions of the registration rights agreement that are applicable to that
holder, including specified indemnification obligations. A holder will not be
permitted to sell notes pursuant to the shelf registration statement unless the
holder has returned to us a completed and signed notice electing to be included
and furnishing the holder's name and other information required to be included
in the related prospectus.
SPECIAL INTEREST.
We will pay additional cash interest on the outstanding notes and exchange
notes, subject to certain exceptions,
(1) if we fail to file an exchange offer registration statement with the
SEC on or prior to the 90th day after the date of original issue of the
outstanding notes,
(2) if the exchange offer registration statement is not declared effective
by the SEC on or prior to the 180th day after the date of original issue of the
outstanding notes or, if obligated to file a shelf registration statement
pursuant to clause 2(A) above, a shelf registration statement is not declared
effective by the SEC on or prior to the 180th day after the date of original
issue of the outstanding notes,
(3) if the exchange offer is not consummated on or before the 40th day
after the exchange offer registration statement is declared effective,
(4) if obligated to file the shelf registration statement pursuant to
clause 2(B) above, we fail to file the shelf registration statement with the SEC
on or prior to the 30th day, or the "shelf filing date," after the date on which
the obligation to file a shelf registration statement arises,
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(5) if obligated to file a shelf registration statement pursuant to clause
2(B) above, the shelf registration statement is not declared effective on or
prior to the 90th day after the shelf filing date, or
(6) after the exchange offer registration statement or the shelf
registration statement, as the case may be, is declared effective, such
registration statement thereafter ceases to be effective or usable, subject to
certain exceptions.
The rate of additional interest will accrue on the principal amount of the
outstanding notes and the exchange notes, in addition to the stated interest on
the outstanding notes and the exchange notes, from and including the date on
which an event referred to in clauses (1) through (6) above shall occur, each
event being a "registration default," to the date on which all such events have
been cured or if earlier, the date on which the outstanding notes may first be
resold in reliance on Rule 144(k). The additional interest will accrue at a rate
of 0.25% per annum for the first 90 day period immediately following the
occurrence of such registration default and shall increase by an additional
0.25% per annum with respect to each subsequent 90-day period until all
registration defaults have been cured up to a maximum additional interest rate
of 1.0%.
TERMS OF THE EXCHANGE OFFER
Upon satisfaction or waiver of all the conditions of the exchange offer, we
will accept any and all outstanding notes properly tendered and not validly
withdrawn prior to the expiration date and will promptly issue the exchange
notes. See "-- Conditions to the Exchange Offer" and "-- Procedures for
Tendering Outstanding Notes." We will issue $1,000 principal amount of exchange
notes in exchange for each $1,000 principal amount of outstanding notes accepted
in the exchange offer. As of the date of this prospectus, there are $550,000,000
aggregate principal amount of outstanding notes. Holders may tender some or all
of their outstanding notes pursuant to the exchange offer. However, outstanding
notes may be tendered only in integral multiples of $1,000.
The exchange notes are identical to the outstanding notes except for the
elimination of certain transfer restrictions and registration rights pertaining
to the outstanding notes. The exchange notes will evidence the same debt as the
outstanding notes and will be issued pursuant to, and entitled to the benefits
of, the indenture pursuant to which the outstanding notes were issued and will
be deemed one issue of notes, together with the outstanding notes.
This prospectus, together with the letter of transmittal, is being sent to
all registered holders and to others believed to have beneficial interests in
the outstanding notes. Holders of outstanding notes do not have any appraisal or
dissenters' rights under the indenture in connection with the exchange offer. We
intend to conduct the exchange offer in accordance with the applicable
requirements of the Securities Act, the Exchange Act and the rules and
regulations of the SEC promulgated thereunder.
For purposes of the exchange offer, we will be deemed to have accepted
validly tendered outstanding notes when, and if, we have given oral or written
notice thereof to the exchange agent. The exchange agent will act as our agent
for the purpose of distributing the appropriate exchange notes from us to the
tendering holders. If we do not accept any tendered outstanding notes because of
an invalid tender, the occurrence of certain other events set forth in this
prospectus or otherwise, we will return the unaccepted outstanding notes,
without expense, to the tendering holder thereof promptly after the expiration
date.
Holders who tender outstanding notes in the exchange offer will not be
required to pay brokerage commissions or fees or, except as set forth below
under "-- Transfer Taxes," transfer taxes with respect to the exchange of
outstanding notes pursuant to the exchange offer. We will pay all charges and
expenses, other than certain applicable taxes, in connection with the exchange
offer. See "-- Fees and Expenses."
EXPIRATION DATE; EXTENSIONS; AMENDMENTS
The term "expiration date" shall mean 5:00 p.m., New York City time, on
October 14, 2003, for the exchange offer unless we, in our sole discretion,
extend the exchange offer, in which case the term "expiration date" shall mean
the latest date and time to which the exchange offer is extended. In order to
extend the exchange offer, we will notify the exchange agent by oral or written
notice and each appropriate registered holder by means of press release or other
public announcement of any extension, in each case, prior to 9:00 a.m., New York
City time, on the next business day after the previously scheduled expiration
date. We reserve the right, in our sole discretion,
o to delay accepting any outstanding notes,
o to extend the exchange offer,
o to terminate the exchange offer and not accept any outstanding notes
if each condition set forth below under "-- Conditions to the Exchange
Offer" shall not have been satisfied or waived by us, or
o to amend the terms of the exchange offer in any manner.
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We will notify the exchange agent of any delay, extension, termination or
amendment by oral or written notice. We will also notify each registered holder
of any amendment. We will give to the exchange agent written confirmation of any
oral notice.
EXCHANGE DATE
As soon as practicable after the close of the exchange offer, we will
accept for exchange all outstanding notes properly tendered and not validly
withdrawn prior to 5:00 p.m., New York City time, on the expiration date in
accordance with the terms of this prospectus and the letter of transmittal.
CONDITIONS TO THE EXCHANGE OFFER
Notwithstanding any other provisions of the exchange offer or any extension
of the exchange offer, and subject to our obligations under the registration
rights agreement, we
o shall not be required to accept any outstanding notes for exchange,
o shall not be required to issue exchange notes in exchange for any
outstanding notes and
o may terminate or amend the exchange offer
if, at any time before the acceptance of outstanding notes for exchange, any of
the following events shall occur:
o any injunction, order or decree shall have been issued by any court or
any governmental agency that would prohibit, prevent or otherwise
materially impair our ability to proceed with the exchange offer;
o any law, statute, rule or regulation is proposed, adopted or enacted
which, in our sole judgment, might materially impair our ability to
proceed with the exchange offer or materially impair the contemplated
benefits of the exchange offer to us;
o any governmental approval has not been obtained, which approval we
shall, in our sole discretion, deem necessary for the consummation of
the exchange offer as contemplated hereby; or
o the exchange offer will violate any applicable law or any applicable
interpretation of the staff of the SEC.
The foregoing conditions are for our sole benefit and may be asserted by us
regardless of the circumstances giving rise to any of those conditions or may be
waived by us in whole or in part at any time and from time to time in our sole
discretion. Our failure at any time to exercise any of the foregoing rights
shall not be deemed a waiver of any of those rights, and those rights shall be
deemed ongoing rights that may be asserted at any time and from time to time.
In addition, we will not accept for exchange any outstanding notes
tendered, and no exchange notes will be issued in exchange for any tendered
outstanding notes, if at such time any stop order shall be threatened by the SEC
or be in effect with respect to the registration statement of which this
prospectus is a part or the qualification of the indenture for the notes under
the Trust Indenture Act of 1939, as amended.
The exchange offer is not conditioned on any minimum aggregate principal
amount of outstanding notes being tendered for exchange.
CONSEQUENCES OF FAILURE TO EXCHANGE
Any outstanding notes not tendered pursuant to the exchange offer will
remain outstanding and will continue to be entitled to the benefits of the
indenture and continue to accrue interest. The outstanding notes will remain
"restricted securities" within the meaning of the Securities Act. Accordingly,
prior to the date that is one year after the later of the issue date and the
last date on which we or any of our affiliates was the owner of the outstanding
notes, the outstanding notes may be resold only:
o to us;
o to a person who the seller reasonably believes is a "qualified
institutional buyer" purchasing for its own account or for the account
of another "qualified institutional buyer" in compliance with the
resale limitations of Rule 144A;
o pursuant to the limitations on resale provided by Rule 144 under the
Securities Act;
o pursuant to the resale provisions of Rule 904 of Regulation S under
the Securities Act;
o pursuant to an effective registration statement under the Securities
Act; or
o pursuant to any other available exemption from the registration
requirements of the Securities Act,
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subject, in each of the foregoing cases, to compliance with applicable state
securities laws. As a result, the liquidity of the market for non-tendered
outstanding notes could be adversely affected upon completion of the exchange
offer.
FEES AND EXPENSES
We will not make any payments to brokers, dealers or others soliciting
acceptances of the exchange offer. The principal solicitation is being made by
mail; however, additional solicitations may be made in person or by telephone by
our officers and employees.
Expenses incurred in connection with the exchange offer will be paid by us.
Such expenses include, among others, the fees and expenses of the trustee and
the exchange agent, accounting and legal fees, printing costs and other
miscellaneous fees and expenses.
ACCOUNTING TREATMENT
We will not recognize any gain or loss for accounting purposes upon the
consummation of the exchange offer. We will amortize the expenses of the
exchange offer as additional interest expense over the term of the exchange
notes.
PROCEDURES FOR TENDERING OUTSTANDING NOTES
The tender of outstanding notes pursuant to any of the procedures set forth
in this prospectus and in the letter of transmittal will constitute a binding
agreement between the tendering holder and us in accordance with the terms and
subject to the conditions set forth in this prospectus and in the letter of
transmittal. The tender of outstanding notes will constitute an agreement to
deliver good and marketable title to all tendered outstanding notes prior to the
expiration date free and clear of all liens, charges, claims, encumbrances,
interests and restrictions of any kind.
Except as provided in "-- Guaranteed Delivery Procedures," unless the
outstanding notes being tendered are deposited by you with the exchange agent
prior to the expiration date and are accompanied by a properly completed and
duly executed letter of transmittal, we may, at our option, reject the tender.
Issuance of exchange notes will be made only against deposit of tendered
outstanding notes and delivery of all other required documents. Notwithstanding
the foregoing, The Depository Trust Company, or "DTC," participants tendering
through its Automated Tender Offer Program, or "ATOP," will be deemed to have
made valid delivery where the exchange agent receives an agent's message, as
defined below, prior to the expiration date.
Accordingly, to properly tender outstanding notes, the following procedures
must be followed:
NOTES HELD THROUGH A CUSTODIAN. Each beneficial owner holding outstanding
notes through a DTC participant must instruct the DTC participant to cause its
outstanding notes to be tendered in accordance with the procedures set forth in
this prospectus.
NOTES HELD THROUGH DTC. Pursuant to an authorization given by DTC to the
DTC participants, each DTC participant holding outstanding notes through DTC
must
o electronically transmit its acceptance through ATOP, and DTC will then
edit and verify the acceptance, execute a book-entry delivery to the
exchange agent's account at DTC and send an agent's message to the
exchange agent for its acceptance, or
o comply with the guaranteed delivery procedures set forth below and in
a notice of guaranteed delivery. See "-- Guaranteed Delivery
Procedures."
Promptly after the date of this prospectus, the exchange agent will
establish an account at DTC for purposes of the exchange offer with respect to
outstanding notes held through DTC. Any financial institution that is a DTC
participant may make book-entry delivery of interests in outstanding notes into
the exchange agent's account through ATOP. However, although delivery of
interests in the outstanding notes may be effected through book-entry transfer
into the exchange agent's account through ATOP, an agent's message in connection
with such book-entry transfer, and any other required documents, must be, in any
case, transmitted to and received by the exchange agent at its address set forth
under "-- Exchange Agent," or the guaranteed delivery procedures set forth below
must be complied with, in each case, prior to the expiration date. DELIVERY OF
DOCUMENTS TO DTC DOES NOT CONSTITUTE DELIVERY TO THE EXCHANGE AGENT. The
confirmation of a book-entry transfer into the exchange agent's account at DTC
as described above is referred to herein as a "Book-Entry Confirmation."
The term "agent's message" means a message transmitted by DTC to, and
received by, the exchange agent and forming a part of the book-entry
confirmation, which states that DTC has received an express acknowledgment from
each DTC participant tendering through ATOP that that DTC participant has
received a letter of transmittal and agrees to be bound by the terms of the
letter of transmittal and that we may enforce such agreement against such DTC
participants.
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Cede & Co., as the holder of the global note, will tender a portion of the
global note equal to the aggregate principal amount due at the stated maturity
for which instructions to tender are given by DTC participants.
By tendering, each holder and each DTC participant will represent to us
that, among other things:
o it is not our affiliate;
o it is not a broker-dealer tendering outstanding notes acquired
directly from us for its own account;
o it is acquiring the exchange notes in its ordinary course of business;
and
o it is not engaged in, and does not intend to engage in, and has no
arrangement or understanding with any person to participate in, a
distribution of the exchange notes.
Unless waived by us, we will not accept any alternative, conditional,
irregular or contingent tenders. By transmitting an acceptance through ATOP,
each tendering holder waives any right to receive any notice of the acceptance
for purchase of its outstanding notes.
We will resolve all questions as to the validity, form, eligibility
(including time of receipt) and acceptance of tendered outstanding notes, and
that determination will be final and binding. We reserve the absolute right to
reject any or all tenders that are not in proper form or the acceptance of which
may, in the opinion of our counsel, be unlawful. We also reserve the absolute
right to waive any condition to the exchange offer and any irregularities or
conditions of tender as to particular outstanding notes. Our interpretation of
the terms and conditions of the exchange offer (including the instructions in
the letter of transmittal) will be final and binding. Unless waived, any
irregularities in connection with tenders must be cured within such time as we
shall determine. We, along with the exchange agent, shall be under no duty to
give notification of defects in such tenders and shall not incur liabilities for
failure to give such notification. Tenders of outstanding notes will not be
deemed to have been made until those irregularities have been cured or waived.
Any outstanding notes received by the exchange agent that are not properly
tendered and as to which the irregularities have not been cured or waived will
be returned by the exchange agent to the tendering holder, unless otherwise
provided in the letter of transmittal, as soon as practicable following the
expiration date.
LETTERS OF TRANSMITTAL AND OUTSTANDING NOTES MUST BE SENT ONLY TO THE EXCHANGE
AGENT. DO NOT SEND LETTERS OF TRANSMITTAL OR OUTSTANDING NOTES TO US OR DTC.
The method of delivery of outstanding notes, letters of transmittal, any
required signature guarantees and all other required documents, including
delivery through DTC and any acceptance through ATOP, is at the election and
risk of the persons tendering and delivering acceptances or letters of
transmittal and, except as otherwise provided in the letter of transmittal,
delivery will be deemed made only when actually received by the exchange agent.
If delivery is by mail, it is suggested that the holder use properly insured,
registered mail with return receipt requested, and that the mailing be made
sufficiently in advance of the expiration date to permit delivery to the
exchange agent prior to the expiration date.
GUARANTEED DELIVERY PROCEDURES
DTC participants holding outstanding notes through DTC who wish to cause
their outstanding notes to be tendered, but who cannot transmit their
acceptances through ATOP prior to the expiration date, may cause a tender to be
effected if:
o guaranteed delivery is made by or through a firm or other entity
identified in Rule 17Ad-15 under the Exchange Act, including the
following, which we call "eligible institutions":
o a bank;
o a broker, dealer, municipal securities dealer, municipal
securities broker, government securities dealer or government
securities broker;
o a credit union;
o a national securities exchange, registered securities association
or clearing agency; or
o a savings institution that is a participant in a Securities
Transfer Association recognized program;
o prior to the expiration date, the exchange agent receives from any of
the above institutions a properly completed and duly executed notice
of guaranteed delivery, by mail, hand delivery, facsimile transmission
or overnight courier, substantially in the form provided with this
prospectus; and
67
o book-entry confirmation and an agent's message in connection therewith
are received by the exchange agent within three New York Stock
Exchange trading days after the date of the execution of the notice of
guaranteed delivery.
WITHDRAWAL RIGHTS
You may withdraw tenders of outstanding notes, or any portion of your
outstanding notes, in integral multiples of $1,000 principal amount due at the
stated maturity, at any time prior to 5:00 p.m., New York City time, on the
expiration date. Any outstanding notes properly withdrawn will be deemed to be
not validly tendered for purposes of the exchange offer.
DTC participants holding outstanding notes who have transmitted their
acceptances through ATOP may, prior to 5:00 p.m., New York City time, on the
expiration date, withdraw the instruction given thereby by delivering to the
exchange agent, at its address set forth under "-- Exchange Agent," a written,
telegraphic or facsimile notice of withdrawal of such instruction. Such notice
of withdrawal must contain the name and number of the DTC participant, the
principal amount of outstanding notes to which such withdrawal relates and the
signature of the DTC participant. Receipt of such written notice of withdrawal
by the exchange agent effectuates a withdrawal.
A withdrawal of a tender of outstanding notes by a DTC participant or a
holder, as the case may be, may be rescinded only by a new transmission of an
acceptance through ATOP or execution and delivery of a new letter of
transmittal, as the case may be, in accordance with the procedures described
herein.
A withdrawal of an instruction must be executed by a DTC participant in the
same manner as the person's name appears on its transmission through ATOP to
which such withdrawal relates. If a notice of withdrawal is signed by a trustee,
partner, executor, administrator, guardian, attorney-in-fact, agent, officer of
a corporation or other person acting in a fiduciary or representative capacity,
that person must so indicate when signing and must submit with the revocation
appropriate evidence of authority to execute the notice of withdrawal. A DTC
participant may withdraw an instruction only if that withdrawal complies with
the provisions of this prospectus.
EXCHANGE AGENT
The Bank of New York will act as exchange agent for the exchange offer.
You should direct all executed letters of transmittal to the exchange agent
at one of the addresses set forth below. You should direct questions and
requests for assistance, requests for additional copies of this prospectus or of
the letter of transmittal and requests for copies of the notice of guaranteed
delivery to the exchange agent, addressed as follows:
By registered or certified mail:
The Bank of New York
Corporate Trust Operations
Reorganization Unit
101 Barclay Street - 7 East
New York, New York 10286
Attn: Giselle Guadalupe
By hand/overnight courier:
The Bank of New York
Corporate Trust Services Window, Ground Level
101 Barclay Street
New York, New York 10286
Attn: Giselle Guadalupe
By facsimile (eligible institutions only):
(212) 298-1915
By telephone inquiries:
(212) 815-6331
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DELIVERY TO AN ADDRESS OTHER THAN AS SET FORTH ABOVE WILL NOT CONSTITUTE A
VALID DELIVERY.
TRANSFER TAXES
Holders of outstanding notes who tender their outstanding notes for
exchange notes will not be obligated to pay any transfer taxes in connection
therewith, except that holders who instruct us to register exchange notes in the
name of, or request that outstanding notes not tendered or not accepted in the
exchange offer be returned to, a person other than the registered tendering
holder will be responsible for the payment of any applicable transfer tax
thereon.
OTHER
Participation in the exchange offer is voluntary. You should carefully
consider whether to accept the exchange offer. You should consult your financial
and tax advisors in making your own decision on what action to take.
We may in the future seek to acquire untendered outstanding notes in open
market or privately negotiated transactions, through subsequent exchange offers
or otherwise. We have no present plans to acquire any outstanding notes that are
not tendered in the exchange offer or to file a registration statement to permit
resales of any untendered outstanding notes.
DESCRIPTION OF THE EXCHANGE NOTES
The Outstanding Notes were issued and the exchange notes, the "Exchange
Notes," will be issued under an Indenture, or the "Indenture," dated as of
February 27, 2003 between us and The Bank of New York, as Trustee. We refer to
the Outstanding Notes, the Exchange Notes, and any other notes issued under the
Indenture as the "Notes." The terms of the Exchange Notes include those stated
in the Indenture and those made part of the Indenture by reference to the Trust
Indenture Act.
Certain terms used in this description are defined under the subheading "--
Certain Definitions." In this description, the word "Company" refers only to
CITGO Petroleum Corporation and not to any of its subsidiaries.
The following description is only a summary of the material provisions of
the Exchange Notes and the Indenture. We urge you to read the Indenture because
it, not this description, defines your rights as holders of the Exchange Notes.
You may request a copy of the Indenture at our address set forth under the
heading "Where You Can Find More Information."
The terms of the Exchange Notes are identical in all material respects to
the terms of the Outstanding Notes, except that the transfer restrictions and
registration rights relating to the Outstanding Notes do not apply to the
Exchange Notes. If we do not complete the exchange offer by October 5, 2003,
holders of Outstanding Notes that have complied with their obligations under the
registration rights agreement will be entitled to additional interest in an
amount equal to a rate of 0.25% per annum for the first 90-day period
immediately following the occurrence of a registration default, and such rate
will increase by an addition 0.25% per annum with respect to each subsequent
90-day period until all registration defaults have been cured, up to a maximum
additional interest rate of 1.0% per annum. We will pay such additional interest
on regular interest payment dates. Such additional interest will be in addition
to any other interest payable from time to time with respect to the Outstanding
Notes.
BRIEF DESCRIPTION OF THE EXCHANGE NOTES
The Exchange Notes:
o will be unsecured senior obligations of the Company; and
o will be senior in right of payment to any Subordinated Obligations of the
Company.
PRINCIPAL, MATURITY AND INTEREST
The Company will issue the Exchange Notes initially with a maximum
aggregate principal amount of $550 million. The Company will issue the Exchange
Notes in denominations of $1,000 principal amount and any integral multiple of
$1,000. The Exchange Notes will mature on February 1, 2011. Subject to our
compliance with the covenant described under the subheading "-- Certain
Covenants -- Limitation on Indebtedness," we are entitled to, without the
consent of the holders, issue more Notes under the Indenture on the same terms
and conditions and with the same CUSIP numbers as the Notes in an unlimited
aggregate principal amount (the "Additional Notes"). The Notes and the
Additional Notes, if any, will be treated as a single class for all purposes of
the Indenture, including waivers, amendments, redemptions and offers to
purchase. Unless the context otherwise requires, for all purposes of the
Indenture and this "Description of the Exchange Notes," references to the Notes
include any Additional Notes actually issued.
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Interest on the Exchange Notes will accrue at the rate of 11 3/8% per annum
and will be payable semiannually in arrears on February 1 and August 1,
commencing on February 1, 2004. We will make each interest payment to the
holders of record of the Exchange Notes on the immediately preceding January 15
or July 15, as the case may be. We will pay interest on overdue principal at 1%
per annum in excess of the above rate and will pay interest on overdue
installments of interest at such higher rate to the extent lawful.
Interest on the Exchange Notes will accrue from the most recent interest
payment date to which interest has been paid on the Outstanding Notes or, if no
interest has been paid, February 27, 2003. Interest will be computed on the
basis of a 360-day year comprised of twelve 30-day months.
OPTIONAL REDEMPTION
Except as set forth below, we will not be entitled to redeem the Exchange
Notes prior to their stated maturity.
On and after February 1, 2007, we may at our option redeem all or a portion
of the Exchange Notes upon not less than 30 nor more than 60 days' notice, at
the redemption prices (expressed as percentages of principal amount) set forth
below, plus accrued and unpaid interest to the redemption date (subject to the
right of Holders on the relevant record date to receive interest due on the
relevant interest payment date), if redeemed during the 12-month period
commencing on February 1 of the following years:
<Table>
<Caption>
REDEMPTION
YEAR PRICE
- ---------------------------- ----------
2007 105.688%
2008 102.843%
2009 and thereafter 100.000%
</Table>
Prior to February 1, 2006, we may at our option on one or more occasions
redeem Notes (which includes Additional Notes, if any) in an aggregate principal
amount of not to exceed 35% of the aggregate principal amount of the Notes
(which includes Additional Notes, if any) originally issued at a redemption
price (expressed as a percentage of principal amount) of 111.375%, plus accrued
and unpaid interest to the redemption date, with the net cash proceeds from one
or more Equity Offerings subsequent to the Issue Date; provided, however, that
(1) at least 65% of such aggregate principal amount of Notes (which
includes Additional Notes, if any) remains outstanding immediately after the
occurrence of each such redemption (other than Notes held, directly or
indirectly, by the Company or its Affiliates); and
(2) each such redemption occurs within 60 days after the date of the
related Equity Offering.
Prior to February 1, 2007, we may at our option redeem all, but not less
than all, of the Notes at a redemption price equal to 100% of the principal
amount of the Notes plus the Applicable Premium as of, and accrued and unpaid
interest to, the redemption date (subject to the right of Holders on the
relevant record date to receive interest due on the relevant interest payment
date). Notice of such redemption must be mailed by first-class mail to each
Holder's registered address, not less than 30 nor more than 60 days prior to the
redemption date.
"Applicable Premium" means, with respect to a Note at any redemption date,
the greater of (i) 1.00% of the principal amount of such Note and (ii) the
excess of (A) the present value at such redemption date of (1) the redemption
price of such Note on February 1, 2007 (such redemption price being described in
the second paragraph of this "-- Optional Redemption" section exclusive of any
accrued interest) plus (2) all required remaining scheduled interest payments
due on such Note through February 1, 2007, computed using a discount rate equal
to the Adjusted Treasury Rate, over (B) the principal amount of such Note on
such redemption date.
"Adjusted Treasury Rate" means, with respect to any redemption date, (i)
the yield, under the heading which represents the average for the immediately
preceding week, appearing in the most recently published statistical release
designated "H.15(519)" or any successor publication which is published weekly by
the Board of Governors of the Federal Reserve System and which establishes
yields on actively traded United States Treasury securities adjusted to constant
maturity under the caption "Treasury Constant Maturities," for the maturity
corresponding to the Comparable Treasury Issue (if no maturity is within three
months before or after February 1, 2007, yields for the two published maturities
most closely corresponding to the Comparable Treasury Issue shall be determined
and the Adjusted Treasury Rate shall be interpolated or extrapolated from such
yields on a straight line basis, rounding to the nearest month) or (ii) if such
release (or any successor release) is not published during the week preceding
the calculation date or does not contain such yields, the rate per year equal to
the semi-annual equivalent yield to maturity of the Comparable Treasury Issue
(expressed as a percentage of its principal amount) equal to the Comparable
Treasury Price for such redemption date, in each case calculated on the third
Business Day immediately preceding the redemption date, plus 0.50%.
70
"Comparable Treasury Issue" means the United States Treasury security
selected by the Quotation Agent as having a maturity comparable to the remaining
term from the redemption date to February 1, 2007, that would be utilized, at
the time of selection and in accordance with customary financial practice, in
pricing new issues of corporate debt securities of a maturity most nearly equal
to February 1, 2007.
"Comparable Treasury Price" means, with respect to any redemption date, if
clause (ii) of the Adjusted Treasury Rate is applicable, the average of three,
or such lesser number as is obtained by the Trustee, Reference Treasury Dealer
Quotations for such redemption date.
"Quotation Agent" means the Reference Treasury Dealer selected by the
Trustee after consultation with the Company.
"Reference Treasury Dealer" means Credit Suisse First Boston LLC and its
successors and assigns, and two other nationally recognized investment banking
firms selected by the Company that are primary U.S. Government securities
dealers.
"Reference Treasury Dealer Quotations" means, with respect to each
Reference Treasury Dealer and any redemption date, the average, as determined by
the Trustee, of the bid and asked prices for the Comparable Treasury Issue,
expressed in each case as a percentage of its principal amount, quoted in
writing to the Trustee by such Reference Treasury Dealer at 5:00 p.m., New York
City Time, on the third Business Day immediately preceding such redemption date.
SELECTION AND NOTICE OF REDEMPTION
If we are redeeming less than all the Notes at any time, the Trustee will
select Notes on a pro rata basis, by lot or by such other method as the Trustee
in its sole discretion shall deem to be fair and appropriate.
We will redeem Notes of $1,000 principal amount or less in whole and not in
part. We will cause notices of redemption to be mailed by first-class mail at
least 30 but not more than 60 days before the redemption date to each Holder of
Notes to be redeemed at its registered address.
If any Note is to be redeemed in part only, the notice of redemption that
relates to that Note will state the portion of the principal amount thereof to
be redeemed. We will issue a new Note in a principal amount equal to the
unredeemed portion of the original Note in the name of the Holder upon
cancelation of the original Note. Notes called for redemption become due on the
date fixed for redemption. On and after the redemption date, interest ceases to
accrue on Notes or portions of them called for redemption.
MANDATORY REDEMPTION; OFFERS TO PURCHASE; OPEN MARKET PURCHASES
We are not required to make any mandatory redemption or sinking fund
payments with respect to the Exchange Notes. However, under certain
circumstances, we may be required to offer to purchase Exchange Notes as
described under the captions "-- Change of Control" and "-- Certain Covenants --
Limitation on Sales of Assets and Subsidiary Stock." We may at any time and from
time to time purchase Exchange Notes in the open market or otherwise.
RANKING
SENIOR INDEBTEDNESS VERSUS EXCHANGE NOTES
The indebtedness evidenced by these Exchange Notes will be unsecured and
will rank pari passu in right of payment to the Senior Indebtedness of the
Company, including the Outstanding Notes. As of December 31, 2002, on an as
adjusted basis to give effect to the issuance of the Outstanding Notes and the
use of a portion of the net proceeds therefrom for the repurchase of certain of
our indebtedness and for general corporate purposes, and also to give effect to
the funding of loans under the New Credit Agreement, the Company would have had
$1,764.9 million of Senior Indebtedness outstanding and would have had $545.0
million of total undrawn commitments available under its credit agreements and,
as further adjusted to give effect to the application of a portion of the net
proceeds from the issuance of the Outstanding Notes to the payment of a dividend
to PDV America, the Company would have had $1,861.4 million of Senior
Indebtedness outstanding and would have had $448.5 million of total undrawn
commitments available under its credit agreements. Secured debt and other
secured obligations of the Company will be effectively senior to the Exchange
Notes to the extent of the value of the assets securing such debt or other
obligations. Our obligations to the lenders under the New Credit Agreement are
secured by a pledge of the limited liability company interests of the Pledged
Entities that own our equity interests in the Explorer Pipeline and the Colonial
Pipeline. See "Management's Discussion and Analysis of Financial Condition and
Results of Operations -- Liquidity and Capital Resources." We will also be able
to incur additional secured debt to the extent permitted by the Indenture. See
"-- Certain Covenants -- Limitation on Liens" and "-- Certain Investment Grade
Covenants -- Restrictions on Secured Indebtedness."
71
LIABILITIES OF SUBSIDIARIES VERSUS EXCHANGE NOTES
A substantial portion of our operations are conducted through our
subsidiaries. Claims of creditors of such subsidiaries, including trade
creditors and creditors holding indebtedness or guarantees issued by such
subsidiaries, and claims of preferred stockholders of such subsidiaries
generally will have priority with respect to the assets and earnings of such
subsidiaries over the claims of the Company's creditors, including holders of
the Exchange Notes. Accordingly, the Exchange Notes will be effectively
subordinated to creditors (including trade creditors) and preferred
stockholders, if any, of our subsidiaries.
At December 31, 2002, the total liabilities of our subsidiaries (excluding
intercompany liabilities) were approximately $1,052 million, including trade
payables. Although the Indenture limits the incurrence of Indebtedness and the
issuance of preferred stock by certain of our subsidiaries, such limitations are
subject to a number of significant qualifications. Moreover, the Indenture does
not impose any limitation on the incurrence by such subsidiaries of liabilities
that are not considered Indebtedness under the Indenture. See "-- Certain
Covenants -- Limitation on Indebtedness."
BOOK-ENTRY, DELIVERY AND FORM
The Exchange Notes will be represented by one or more global notes in
registered form without interest coupons, or the "Global Exchange Notes." The
Global Exchange Notes will be deposited upon issuance with the Trustee as
custodian for DTC in New York, New York, and registered in the name of DTC or
its nominee, in each case for credit to an account of a direct or indirect
participant in DTC as described below. So long as DTC or its nominee is the
registered owner of a Global Exchange Note, DTC or such nominee will be
considered the sole record owner or "Holder" of the Notes represented by the
Global Exchange Note for all purposes under the Indenture and the Notes.
Each person owning a beneficial interest in a Global Exchange Note must
rely on the procedures of DTC and on the procedures of the DTC participants to
exercise any rights of a Holder of Notes.
Under current industry practice, in the event that we request any action of
Holders of Notes, or in the event that an owner of a beneficial interest in a
Global Exchange Note desires to take any action that DTC, as Holder of such
Global Exchange Note, is entitled to take, DTC would authorize the DTC
participants to take such action and the DTC participants would authorize
persons owning through such DTC participants to take that action or would
otherwise act upon the instruction of those persons. Neither we nor the Trustee
will have any responsibility or liability for any aspect of the records relating
to or payments made on account of Notes by DTC, or for maintaining, supervising
or reviewing any records of DTC relating to those Notes.
Except as set forth below, the Global Exchange Notes may be transferred, in
whole and not in part, only to another nominee of DTC or to a successor of DTC
or its nominee. Beneficial interests in the Global Exchange Notes may not be
exchanged for Exchange Notes in certificated form except in the limited
circumstances described below. See "-- Exchange of Global Exchange Notes for
Certificated Exchange Notes." Except in the limited circumstances described
below, owners of beneficial interests in the Global Exchange Notes will not be
entitled to receive physical delivery of Exchange Notes in certificated form.
Transfers of beneficial interests in the Global Exchange Notes will be
subject to the applicable rules and procedures of DTC and its direct or indirect
participants (as defined below and including, if applicable, those of the
Euroclear System, or "Euroclear," and Clearstream Banking, S.A., or
"Clearstream," which may change from time to time.
DEPOSITORY PROCEDURES
The following description of the operations and procedures of DTC,
Euroclear and Clearstream are provided solely as a matter of convenience. These
operations and procedures are solely within the control of the respective
settlement systems and are subject to changes by them. We take no responsibility
for these operations and procedures and urge investors to contact the system or
their participants directly to discuss these matters.
DTC has advised us that DTC is a limited-purpose trust company created to
hold securities for its participating organizations, or collectively, the
"Participants," and to facilitate the clearance and settlement of transactions
in those securities between Participants through electronic book-entry changes
in accounts of its Participants. The Participants include securities brokers and
dealers, including the initial purchasers, banks, trust companies, clearing
corporations and certain other organizations. Access to DTC's system is also
available to other entities such as banks, brokers, dealers and trust companies
that clear through or maintain a custodial relationship with a Participant,
either directly or indirectly, or collectively, the "Indirect Participants."
Persons who are not Participants may beneficially own securities held by or on
behalf of DTC only through the Participants or the Indirect Participants. The
ownership interests in, and transfers of ownership interests in, each security
held by or on behalf of DTC are recorded on the records of the Participants and
Indirect Participants.
72
DTC has also advised us that, pursuant to procedures established by it:
(1) upon deposit of the Global Exchange Notes, DTC will credit the accounts
of Participants designated by the Participants depositing the Global Exchange
Notes with portions of the principal amount of the Global Exchange Notes; and
(2) ownership of these interests in the Global Exchange Notes will be shown
on, and the transfer of ownership of these interests will be effected only
through, records maintained by DTC, with respect to the Participants, or by the
Participants and the Indirect Participants, with respect to other owners of
beneficial interests in the Global Exchange Notes.
Investors in the Global Exchange Notes who are Participants in DTC's system
may hold their interests therein directly through DTC. Investors in the Global
Exchange Notes who are not Participants may hold their interests therein
indirectly through organizations, including Euroclear and Clearstream, that are
Participants in such system. All interests in a Global Exchange Note, including
those held through Euroclear or Clearstream, may be subject to the procedures
and requirements of DTC. Those interests held through Euroclear or Clearstream
may also be subject to the procedures and requirements of such systems. The laws
of some states require that certain Persons take physical delivery in definitive
form of securities that they own. Consequently, the ability to transfer
beneficial interests in a Global Exchange Note to those Persons will be limited
to that extent. Because DTC can act only on behalf of Participants, which in
turn act on behalf of Indirect Participants, the ability of a Person having
beneficial interests in a Global Exchange Note to pledge such interests to
Persons that do not participate in the DTC system, or otherwise take actions in
respect of such interests, may be affected by the lack of a physical certificate
evidencing such interests.
EXCEPT AS DESCRIBED BELOW, OWNERS OF AN INTEREST IN THE GLOBAL EXCHANGE
NOTES WILL NOT HAVE EXCHANGE NOTES REGISTERED IN THEIR NAMES, WILL NOT RECEIVE
PHYSICAL DELIVERY OF EXCHANGE NOTES IN CERTIFICATED FORM AND WILL NOT BE
CONSIDERED THE REGISTERED OWNERS OR "HOLDERS" THEREOF UNDER THE INDENTURE FOR
ANY PURPOSE.
Payments in respect of the principal of, and interest and premium and
additional interest, if any, on a Global Exchange Note registered in the name of
DTC or its nominee will be payable to DTC in its capacity as the registered
Holder under the Indenture. Under the terms of the Indenture, the Company and
the Trustee will treat the Persons in whose names the notes, including the
Global Exchange Notes, are registered as the owners of the Exchange Notes for
the purpose of receiving payments and for all other purposes. Consequently,
neither the Company nor the Trustee or any agent of the Company or the Trustee
has or will have any responsibility or liability for:
(1) any aspect of DTC's records or any Participant's or Indirect
Participant's records relating to or payments made on account of beneficial
ownership interests in the Global Exchange Notes or for maintaining, supervising
or reviewing any of DTC's records or any Participant's or Indirect Participant's
records relating to the beneficial ownership interests in the Global Exchange
Notes; or
(2) any other matter relating to the actions and practices of DTC or any of
its Participants or Indirect Participants.
DTC has advised us that its current practice, upon receipt of any payment
in respect of securities such as the Exchange Notes (including principal and
interest), is to credit the accounts of the relevant Participants with the
payment on the payment date unless DTC has reason to believe it will not receive
payment on such payment date. Each relevant Participant is credited with an
amount proportionate to its beneficial ownership of an interest in the principal
amount of the relevant security as shown on the records of DTC. Payments by the
Participants and the Indirect Participants to the beneficial owners of Exchange
Notes will be governed by standing instructions and customary practices, will be
the responsibility of the Participants or the Indirect Participants and will not
be the responsibility of DTC, the Trustee or the Company. Neither the Company
nor the Trustee will be liable for any delay by DTC or any of its Participants
in identifying the beneficial owners of the Exchange Notes, and the Company and
the Trustee may conclusively rely on and will be protected in relying on
instructions from DTC or its nominee for all purposes.
Transfers between Participants in DTC will be effected in accordance with
DTC's procedures, and will be settled in same-day funds, and transfers between
participants in Euroclear and Clearstream will be effected in accordance with
their respective rules and operating procedures.
Cross-market transfers between the Participants in DTC, on the one hand,
and Euroclear or Clearstream participants, on the other hand, will be effected
through DTC in accordance with DTC's rules on behalf of Euroclear or
Clearstream, as the case may be, by its respective depositary; however, such
cross-market transactions will require delivery of instructions to Euroclear or
Clearstream, as the case may be, by the counterparty in such system in
accordance with the rules and procedures and within the established deadlines
(Brussels time) of such system. Euroclear or Clearstream, as the case may be,
will, if the transaction meets its settlement requirements, deliver instructions
to its respective depositary to take action to effect final settlement on its
behalf of delivering or receiving interests in the relevant Global Exchange Note
in DTC, and making or receiving payment in accordance with normal procedures for
same-day funds settlement applicable to DTC. Euroclear participants and
Clearstream participants may not deliver instructions directly to the
depositories for Euroclear or Clearstream.
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DTC has advised the Company that it will take any action permitted to be
taken by a Holder of Exchange Notes only at the direction of one or more
Participants to whose account DTC has credited the interests in the Global
Exchange Notes and only in respect of such portion of the aggregate principal
amount of the Exchange Notes as to which such Participant or Participants has or
have given such direction. However, if there is an Event of Default under the
Exchange Notes, DTC reserves the right to exchange the Global Exchange Notes for
legended Exchange Notes in certificated form, and to distribute such Exchange
Notes to its Participants.
Although DTC, Euroclear and Clearstream have agreed to the foregoing
procedures to facilitate transfers of interests in the Global Exchange Notes
among participants in DTC, Euroclear and Clearstream, they are under no
obligation to perform or to continue to perform such procedures, and may
discontinue such procedures at any time. Neither the Company nor the Trustee or
any of their respective agents will have any responsibility for the performance
by DTC, Euroclear or Clearstream or their respective participants or indirect
participants of their respective obligations under the rules and procedures
governing their operations.
EXCHANGE OF GLOBAL EXCHANGE NOTES FOR CERTIFICATED EXCHANGE NOTES
A Global Exchange Note is exchangeable for Certificated Exchange Notes if:
(1) DTC (a) notifies the Company that it is unwilling or unable to continue
as depositary for the Global Exchange Notes and DTC fails to appoint a successor
depositary or (b) has ceased to be a clearing agency registered under the
Exchange Act;
(2) the Company, at its option, notifies the Trustee in writing that it
elects to cause the issuance of the Certificated Exchange Notes; or
(3) there has occurred and is continuing an Event of Default with respect
to the Exchange Notes.
In addition, beneficial interests in a Global Exchange Note may be
exchanged for Certificated Exchange Notes under prior written notice given to
the Trustee by or on behalf of DTC in accordance with the Indenture. In all
cases, Certificated Exchange Notes delivered in exchange for any Global Exchange
Note or beneficial interests in Global Exchange Notes will be registered in the
names, and issued in any approved denominations, requested by or on behalf of
the depositary, in accordance with its customary procedures.
SAME DAY SETTLEMENT AND PAYMENT
The Company will make payments in respect of the Exchange Notes represented
by the Global Exchange Notes (including principal, premium, if any, interest and
additional interest, if any) by wire transfer of immediately available funds to
the accounts specified by the Global Exchange Note Holder. The Company will make
all payments of principal, interest and premium and additional interest, if any,
with respect to Certificated Exchange Notes by wire transfer of immediately
available funds to the accounts specified by the Holders of the Certificated
Exchange Notes or, if no such account is specified, by mailing a check to each
such Holder's registered address. The Exchange Notes represented by the Global
Exchange Notes are expected to be eligible to trade in the PORTAL market and to
trade in DTC's Same-Day Funds Settlement System, and any permitted secondary
market trading activity in those Exchange Notes will, therefore, be required by
DTC to be settled in immediately available funds. The Company expects that
secondary trading in any Certificated Exchange Notes will also be settled in
immediately available funds.
Because of time zone differences, the securities account of a Euroclear or
Clearstream participant purchasing an interest in a Global Exchange Note from a
Participant in DTC will be credited, and any such crediting will be reported to
the relevant Euroclear or Clearstream participant, during the securities
settlement processing day (which must be a business day for Euroclear and
Clearstream) immediately following the settlement date of DTC. DTC has advised
the Company that cash received in Euroclear or Clearstream as a result of sales
of interests in a Global Exchange Note by or through a Euroclear or Clearstream
participant to a Participant in DTC will be received with value on the
settlement date of DTC but will be available in the relevant Euroclear or
Clearstream cash account only as of the business day for Euroclear or
Clearstream following DTC's settlement date.
CHANGE OF CONTROL
Upon the occurrence of a Change of Control, each Holder shall have the
right to require that the Company repurchase such Holder's Notes at a purchase
price in cash equal to 101% of the principal amount thereof on the date of
purchase 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).
"Change of Control" means any of the following events:
(1) prior to the first public offering of common stock of the Company, the
Permitted Holder ceases to be the "beneficial owner" (as defined in Rules 13d-3
and 13d-5 under the Exchange Act), directly or indirectly, of a majority in the
aggregate of the total voting
74
power of the Voting Stock of the Company, whether as a result of issuance of
securities of the Company, any merger, consolidation, liquidation or dissolution
of the Company, or any direct or indirect transfer of securities or otherwise
(for purposes of this clause (1) and clause (2) below, the Permitted Holder
shall be deemed to beneficially own any Voting Stock of a Person (the "specified
person") held by any other Person (the "parent entity") so long as the Permitted
Holder beneficially owns (as so defined), directly or indirectly, in the
aggregate a majority of the voting power of the Voting Stock of the parent
entity);
(2) after the first public offering of common stock of the Company, any
"person" (as such term is used in Sections 13(d) and 14(d) of the Exchange Act),
other than the Permitted Holder, is or becomes the beneficial owner (as defined
in clause (1) above, except that for purposes of this clause (2) such person
shall 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), directly or indirectly, of more than 35% of
the total voting power of the Voting Stock of the Company; provided, however,
that the Permitted Holder beneficially owns (as defined in clause (1) above),
directly or indirectly, in the aggregate a lesser percentage of the total voting
power of the Voting Stock of the Company than such other person and does not
have the right or ability by voting power, contract or otherwise to elect or
designate for election a majority of the Board of Directors of the Company (for
the purposes of this clause (2), such other person shall be deemed to
beneficially own any Voting Stock of a specified person held by a parent entity,
if such other person is the beneficial owner (as defined in this clause (2)),
directly or indirectly, of more than 35% of the voting power of the Voting Stock
of such parent entity and the Permitted Holder beneficially owns (as defined in
clause (1) above), directly or indirectly, in the aggregate a lesser percentage
of the voting power of the Voting Stock of such parent entity and does not have
the right or ability by voting power, contract or otherwise to elect or
designate for election a majority of the board of directors of such parent
entity);
(3) individuals who on the Issue Date constituted the Board of Directors of
the Company (together with any new directors whose election by such Board of
Directors of the Company or whose nomination for election by the shareholders of
the Company, was (A) approved by a vote of 66 2/3% of the directors of the
Company then still in office who were either directors on the Issue Date or
whose election or nomination for election was previously so approved or (B)
approved by the Permitted Holder at a time when the Permitted Holder held,
directly or indirectly, a majority in the aggregate of the total voting power of
the Voting Stock of the Company) cease for any reason to constitute a majority
of the Board of Directors of the Company then in office;
(4) the adoption of a plan relating to the liquidation or dissolution of
the Company; or
(5) the merger or consolidation of the Company with or into another Person
or the merger of another Person with or into the Company, or the sale of all or
substantially all the assets of the Company (determined on a consolidated basis)
to another Person other than (i) a transaction in which the survivor or
transferee is a Person that is controlled by the Permitted Holder or (ii) a
transaction following which (A) in the case of a merger or consolidation
transaction, holders of securities that represented 100% of the Voting Stock of
the Company immediately prior to such transaction (or other securities into
which such securities are converted as part of such merger or consolidation
transaction) own directly or indirectly at least a majority of the voting power
of the Voting Stock of the surviving Person in such merger or consolidation
transaction immediately after such transaction and in substantially the same
proportion as before the transaction and (B) in the case of a sale of assets
transaction, each transferee becomes an obligor in respect of the Exchange Notes
and a Subsidiary of the transferor of such assets;
provided, however, that none of the events set forth above under paragraphs (1)
through (5) of the definition of "Change of Control" shall constitute a Change
of Control if, immediately following the consummation of any such event and
after giving effect thereto, the Exchange Notes have an Investment Grade Rating.
Within 30 days following any Change of Control, we will mail a notice to
each Holder with a copy to the Trustee (the "Change of Control Offer") stating:
(1) that a Change of Control has occurred and that such Holder has the
right to require us to purchase such Holder's Notes at a purchase price in cash
equal to 101% of the principal amount thereof on the date of purchase, 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 on
the relevant interest payment date);
(2) the circumstances and relevant facts regarding such Change of Control;
(3) the purchase date (which shall be no earlier than 30 days nor later
than 60 days from the date such notice is mailed); and
(4) the instructions, as determined by the Company, consistent with the
covenant described hereunder, that a Holder must follow in order to have its
Notes purchased.
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We will not be required to make a Change of Control Offer following 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.
We will comply, to the extent applicable, with the requirements of Section
14(e) of the Exchange Act and any other securities laws or regulations in
connection with the repurchase of Notes as a result of a Change of Control. To
the extent that the provisions of any securities laws or regulations conflict
with the provisions of the covenant described hereunder, we will comply with the
applicable securities laws and regulations and shall not be deemed to have
breached our obligations under the covenant described hereunder by virtue of our
compliance with such securities laws or regulations.
The Change of Control purchase feature of the Notes may in certain
circumstances make more difficult or discourage a sale or takeover of the
Company and, thus, the removal of incumbent management. The Change of Control
purchase feature is a result of negotiations between the Company and the Initial
Purchasers. We have no present intention to engage in a transaction involving a
Change of Control, although it is possible that we could decide to do so in the
future. Subject to the limitations discussed 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 our capital structure or credit ratings.
Restrictions on our ability to Incur additional Indebtedness are contained in
the covenants described under "-- Certain Covenants -- Limitation on
Indebtedness," "-- Certain Covenants -- Limitation on Liens," "-- Certain
Covenants -- Limitation on Sale/Leaseback Transactions," each of which is
applicable only prior to an Investment Grade Rating Event, and in the covenants
described under "-- Certain Investment Grade Covenants -- Restrictions on
Secured Indebtedness" and "-- Certain Investment Grade Covenants -- Restrictions
on Sale/Leaseback Transactions," each of which is applicable following an
Investment Grade Rating Event. Such restrictions can only be waived with the
consent of the holders of a majority in principal amount of the Notes then
outstanding. Except for the limitations contained in such covenants, however,
the Indenture will not contain any covenants or provisions that may afford
holders of the Notes protection in the event of a highly leveraged transaction.
Our Credit Agreements outstanding on the Issue Date provide that the
occurrence of certain change of control events with respect to the Company would
constitute a default thereunder, which in turn could constitute an Event of
Default under the Indenture. In the event a Change of Control occurs at a time
when we are prohibited by our Credit Agreements or other agreements from
purchasing Notes, we may seek the consent of our lenders to the purchase of
Notes or may attempt to refinance the borrowings that contain such prohibition.
If we do not obtain such a consent or repay such borrowings, we will remain
prohibited from purchasing Notes. In such case, our failure to offer to purchase
Notes would constitute an Event of Default under the Indenture, which would, in
turn, constitute a default under our Credit Agreements outstanding on the Issue
Date.
Future indebtedness that we may incur may contain prohibitions on the
occurrence of certain events that would constitute a Change of Control or
require the repurchase of such indebtedness upon a Change of Control. Moreover,
the exercise by the holders of their right to require us to repurchase the Notes
could cause a default under such indebtedness, even if the Change of Control
itself does not, due to the financial effect of such repurchase on us. Finally,
our ability to pay cash to the holders of Notes following the occurrence of a
Change of Control may be limited by our then existing financial resources. There
can be no assurance that sufficient funds will be available when necessary to
make any required repurchases.
The definition of "Change of Control" includes a disposition of all or
substantially all of the assets of the Company to any Person. Although there is
a limited body of case law interpreting the phrase "substantially all," there is
no precise established definition of the phrase under applicable law.
Accordingly, in certain circumstances there may be a degree of uncertainty as to
whether a particular transaction would involve a disposition of "all or
substantially all" of the assets of the Company. As a result, it may be unclear
as to whether a Change of Control has occurred and whether a Holder of Notes may
require the Company to make an offer to repurchase the Notes as described above.
The provisions under the Indenture relative to our obligation to make an
offer to repurchase the Notes as a result of a Change of Control may be waived
or modified with the written consent of the holders of a majority in principal
amount of the Notes.
CERTAIN COVENANTS
The Indenture contains covenants including, among others, those summarized
below. Upon the occurrence of an Investment Grade Rating Event, each of the
covenants (except for clause (1) of "-- Merger and Consolidation" and "-- SEC
Reports") described below will cease to apply to us and our Restricted
Subsidiaries. Instead, each of the covenants described under "-- Certain
Investment Grade Covenants" will apply to us after the occurrence of an
Investment Grade Rating Event.
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LIMITATION ON INDEBTEDNESS
(a) The Company will not, and will not permit any Restricted Subsidiary to,
Incur, directly or indirectly, any Indebtedness; provided, however, that the
Company and the Subsidiary Guarantors, if any, will be entitled to Incur
Indebtedness if, on the date of such Incurrence and after giving effect thereto
on a pro forma basis, no Default has occurred and is continuing and the
Consolidated Coverage Ratio exceeds 2.0 to 1. The Company will cause each
Restricted Subsidiary that Incurs any Indebtedness pursuant to this paragraph
(a) or paragraphs (b)(12) or (b)(17) of this covenant to execute and deliver to
the Trustee, no later than the date of such Incurrence, a supplemental indenture
to the Indenture pursuant to which such Restricted Subsidiary will guarantee
payment of the Exchange Notes on the same terms and conditions as those set
forth in the Indenture.
(b) Notwithstanding the foregoing paragraph (a), the Company and the
Restricted Subsidiaries will be entitled to Incur any or all of the following
Indebtedness:
(1) Indebtedness Incurred by the Company pursuant to the Three-Year Credit
Agreement or the 364-Day Credit Agreement; provided, however, that, immediately
after giving effect to any such Incurrence, the aggregate principal amount of
all Indebtedness Incurred under this clause (1) and then outstanding does not
exceed the greater of (A) $520 million less the sum of all principal payments
with respect to such Indebtedness pursuant to paragraph (a)(3)(A) of the
covenant described under "-- Limitation on Sales of Assets and Subsidiary Stock"
and (B) 50% of the book value of the inventory of the Company and its Restricted
Subsidiaries;
(2) Indebtedness Incurred by the Company pursuant to the New Credit
Agreement; provided, however, that, immediately after giving effect to any such
Incurrence, the aggregate principal amount of all Indebtedness Incurred under
this clause (2) and then outstanding does not exceed $200 million less the sum
of all principal payments with respect to such Indebtedness pursuant to
paragraph (a)(3)(A) of the covenant described under "-- Limitation on Sales of
Assets and Subsidiary Stock;"
(3) Indebtedness Incurred by CITGO Puerto Rico and the Company pursuant to
the CITGO Puerto Rico Credit Agreement; provided, however, that the aggregate
principal amount of all Indebtedness Incurred by CITGO Puerto Rico and the
Company (without duplication in the case of the Company's Guarantee of CITGO
Puerto Rico's Indebtedness thereunder) pursuant to the CITGO Puerto Rico Credit
Agreement does not exceed $25 million less the sum of all principal payments
with respect to such Indebtedness pursuant to paragraph (a)(3)(A) of the
covenant described under "-- Limitation on Sales of Assets and Subsidiary
Stock;"
(4) Indebtedness owed to and held by the Company or a Restricted
Subsidiary; provided, however, that (A) any subsequent issuance or transfer of
any Capital Stock which results in any such Restricted Subsidiary ceasing to be
a Restricted Subsidiary or any subsequent transfer of such Indebtedness (other
than to the Company or a Restricted Subsidiary) shall be deemed, in each case,
to constitute the Incurrence of such Indebtedness by the obligor thereon and (B)
if the Company is the obligor on such Indebtedness, such Indebtedness is
expressly subordinated to the prior payment in full in cash of all obligations
with respect to the Exchange Notes;
(5) the Outstanding Notes and the Exchange Notes (other than any Additional
Notes);
(6) Indebtedness outstanding on the Issue Date (other than Indebtedness
described in clause (1), (3), (4) or (5) of this covenant);
(7) Indebtedness of a Restricted Subsidiary Incurred and outstanding on or
prior to the date on which such Subsidiary was acquired by the Company (other
than Indebtedness Incurred in connection with, or to provide all or any portion
of the funds or credit support utilized to consummate, the transaction or series
of related transactions pursuant to which such Subsidiary became a Subsidiary or
was acquired by the Company); provided, however, that on the date of such
acquisition and after giving pro forma effect thereto, the Company would have
been able to Incur at least $1.00 of additional Indebtedness pursuant to
paragraph (a) of this covenant;
(8) Refinancing Indebtedness in respect of Indebtedness Incurred pursuant
to paragraph (a) or pursuant to clause (5), (6) or (7) or this clause (8);
provided, however, that to the extent such Refinancing Indebtedness directly or
indirectly Refinances Indebtedness of a Subsidiary Incurred pursuant to clause
(7), such Refinancing Indebtedness shall be Incurred only by such Subsidiary or
the Company;
(9) Hedging Obligations entered into in the ordinary course of business to
purchase any raw material, hydrocarbon, refined product or other commodity or to
hedge risks with respect to the Company's or a Restricted Subsidiary's interest
rate, currency, hydrocarbon or refined products therefrom or commodity exposure
and not for speculative purposes;
(10) obligations in respect of tender, performance, government contract,
bid and surety or appeal bonds and completion guarantees provided by the Company
or any Restricted Subsidiary in the ordinary course of business;
77
(11) Indebtedness arising from the honoring by a bank or other financial
institution of a check, draft or similar instrument drawn against insufficient
funds in the ordinary course of business; provided, however, that such
Indebtedness is extinguished within five Business Days of its Incurrence;
(12) Guarantees by Subsidiary Guarantors of Indebtedness of the Company or
any Restricted Subsidiary permitted to be Incurred under the Indenture and Liens
created by Subsidiary Guarantors that constitute Indebtedness securing
Indebtedness of the Company or any Restricted Subsidiary permitted to be
Incurred under the Indenture;
(13) Indebtedness of a Receivables Subsidiary Incurred pursuant to a
Qualified Receivables Transaction;
(14) Indebtedness of Restricted Subsidiaries in an aggregate principal
amount which, when taken together with all other Indebtedness of Restricted
Subsidiaries outstanding on the date of such Incurrence (other than Indebtedness
permitted by any other clause of this paragraph (b)), does not exceed the
greater of (A) $125 million and (B) 5% of Consolidated Net Worth;
(15) Guarantees by the Pledged Entities of Indebtedness of the Company
Incurred pursuant to clause (2) above;
(16) Guarantees by the Company of Indebtedness of Restricted Subsidiaries
Incurred pursuant to clause (14) above; and
(17) Indebtedness of the Company or any Subsidiary Guarantor in an
aggregate principal amount which, when taken together with all other
Indebtedness of the Company and the Subsidiary Guarantors outstanding on the
date of such Incurrence (other than Indebtedness permitted by clauses (1)
through (16) above or paragraph (a)), does not exceed $75 million.
(c) Notwithstanding the foregoing, the Company will not, and will not
permit any Subsidiary Guarantor to, Incur any Indebtedness pursuant to the
foregoing paragraph (b) if the proceeds thereof are used, directly or
indirectly, to Refinance any Subordinated Obligations of the Company or such
Subsidiary Guarantor unless such Indebtedness shall be subordinated to the
Exchange Notes or the Subsidiary Guaranty of such Subsidiary Guarantor, as the
case may be, to at least the same extent as such Subordinated Obligations.
(d) For purposes of determining compliance with this covenant:
(1) any Indebtedness remaining outstanding under the Three-Year Credit
Agreement, the 364-Day Credit Agreement or the CITGO Puerto Rico Credit
Agreement after the application of the net proceeds from the sale of the
Outstanding Notes will be treated as Incurred on the Issue Date under clause (1)
or (3), as applicable, of paragraph (b) above;
(2) any Indebtedness Incurred or outstanding under the New Credit Agreement
on the Issue Date will be treated as Incurred on the Issue Date under clause (2)
of paragraph (b) above;
(3) in the event that an item of Indebtedness (or any portion thereof)
meets the criteria of more than one of the types of Indebtedness described
above, the Company, in its sole discretion, will classify such item of
Indebtedness (or any portion thereof) at the time of Incurrence and will only be
required to include the amount and type of such Indebtedness in one of the above
clauses; and
(4) the Company will be entitled to divide and classify an item of
Indebtedness in more than one of the types of Indebtedness described above.
LIMITATION ON RESTRICTED PAYMENTS
(a) The Company will not, and will not permit any Restricted Subsidiary,
directly or indirectly, to make a Restricted Payment if at the time the Company
or such Restricted Subsidiary makes such Restricted Payment:
(1) a Default shall have occurred and be continuing (or would result
therefrom);
(2) the Company is not entitled to Incur an additional $1.00 of
Indebtedness pursuant to paragraph (a) of the covenant described under "--
Limitation on Indebtedness;"
(3) the aggregate amount of such Restricted Payment and all other
Restricted Payments since the Issue Date would exceed the sum of (without
duplication):
(A) 50% of the Consolidated Net Income accrued during the period (treated
as one accounting period) from the beginning of the fiscal quarter immediately
following the fiscal quarter ending on December 31, 2002, to the end of the most
recent fiscal quarter
78
ending at least 45 days prior to the date of such Restricted Payment (or, in
case such Consolidated Net Income shall be a deficit, minus 100% of such
deficit); plus
(B) 100% of the aggregate net proceeds, including cash and the fair market
value of property other than cash (as determined in good faith by the Board of
Directors of the Company and evidenced by a board resolution) received by the
Company from the issuance or sale of, or as a capital contribution in respect
of, its Capital Stock (other than Disqualified Stock) subsequent to the Issue
Date (other than an issuance or sale to, or contribution by, a Subsidiary of the
Company and other than an issuance or sale to, or contribution by, an employee
stock ownership plan or a trust established by the Company or any of its
Subsidiaries for the benefit of their employees); plus
(C) the amount by which Indebtedness of the Company is reduced on the
Company's balance sheet upon the conversion or exchange subsequent to the Issue
Date of any Indebtedness of the Company convertible or exchangeable for Capital
Stock (other than Disqualified Stock) of the Company (less the amount of any
cash, or the fair value of any other property, distributed by the Company upon
such conversion or exchange); provided, however, that the foregoing amount shall
not exceed the Net Cash Proceeds received by the Company or any Restricted
Subsidiary from the sale of such Indebtedness (excluding Net Cash Proceeds from
sales to a Subsidiary of the Company or to an employee stock ownership plan or
to a trust established by the Company or any of its Subsidiaries for the benefit
of their employees); plus
(D) an amount equal to the sum of (x) the net reduction in the Investments
(other than Permitted Investments) made by the Company or any Restricted
Subsidiary in any Person resulting from repurchases, repayments or redemptions
of such Investments by such Person, proceeds realized on the sale of such
Investment and proceeds representing the return of capital (excluding dividends
and distributions), in each case received by the Company or any Restricted
Subsidiary, and (y) to the extent such Person is an Unrestricted Subsidiary, the
portion (proportionate to the Company's equity interest in such Subsidiary) of
the fair market value of the net assets of such Unrestricted Subsidiary at the
time such Unrestricted Subsidiary is designated a Restricted Subsidiary;
provided, however, that the foregoing sum shall not exceed, in the case of any
such Person or Unrestricted Subsidiary, the amount of Investments (excluding
Permitted Investments) previously made (and treated as a Restricted Payment) by
the Company or any Restricted Subsidiary in such Person or Unrestricted
Subsidiary;
(4) after giving pro forma effect to such Restricted Payment, the Company
would not have Available Liquidity in excess of $250 million, and on the date
the Company or such Restricted Subsidiary makes such Restricted Payment, the
Chief Financial Officer of the Company shall deliver to the Trustee a
certificate to the effect that the Company is in compliance with this paragraph
(4); or
(5) the aggregate amount of such Restricted Payment and all other
Restricted Payments made since the beginning of the Reference Period would
exceed the Free Cash Flow during the Reference Period.
(b) The preceding provisions will not prohibit:
(1) any Restricted Payment made out of the Net Cash Proceeds of the
substantially concurrent sale of, or made by exchange for, Capital Stock of the
Company (other than Disqualified Stock and other than Capital Stock issued or
sold to a Subsidiary of the Company or an employee stock ownership plan or to a
trust established by the Company or any of its Subsidiaries for the benefit of
their employees) or a substantially concurrent cash capital contribution
received by the Company from or on behalf of one or more of its shareholders;
provided, however, that (A) such Restricted Payment shall be excluded in the
calculation of the amount of Restricted Payments and (B) the Net Cash Proceeds
from such sale or such cash capital contribution (to the extent so used for such
Restricted Payment) shall be excluded from the calculation of amounts under
clause (3)(B) of paragraph (a) above;
(2) any purchase, repurchase, redemption, defeasance or other acquisition
or retirement for value of Subordinated Obligations of the Company or any
Restricted Subsidiary made by exchange for, or out of the proceeds of the
substantially concurrent sale of, Subordinated Obligations of such Person which
is permitted to be Incurred pursuant to the covenant described under "--
Limitation on Indebtedness"; provided, however, that such purchase, repurchase,
redemption, defeasance or other acquisition or retirement for value shall be
excluded from the calculation of the amount of Restricted Payments;
(3) dividends paid within 60 days after the date of declaration thereof if
at such date of declaration such dividend would have complied with this
covenant; provided, however, that at the time of payment of such dividend, no
other Default shall have occurred and be continuing (or result therefrom);
provided further, however, that such dividend shall be included in the
calculation of the amount of Restricted Payments;
(4) so long as no Default has occurred and is continuing, the repurchase or
other acquisition of shares of Capital Stock of the Company or any of its
Subsidiaries from employees, former employees, directors or former directors of
the Company or any of its Subsidiaries (or permitted transferees of such
employees, former employees, directors or former directors), pursuant to the
terms of the agreements (including employment agreements) or plans (or
amendments thereto) approved by the Board of Directors of the
79
Company under which such individuals purchase or sell or are granted the option
to purchase or sell, shares of such Capital Stock; provided, however, that the
aggregate amount of such repurchases and other acquisitions shall not exceed $5
million in any calendar year; provided further, however, that such repurchases
and other acquisitions shall be excluded from the calculation of the amount of
Restricted Payments;
(5) dividends or advances to PDV America, the proceeds of which are used by
PDV America to repay its 7 7/8% Senior Notes Due 2003; provided that (A) the
aggregate amount of such dividends or advances shall not exceed $500 million,
(B) such dividends or advances shall only be declared and paid, as applicable,
on or after the seventh day immediately prior to the maturity date of the 7 7/8%
Senior Notes Due 2003 of PDV America, (C) on the date of payment of any such
dividends or advances, the Chief Financial Officer of the Company shall have
delivered to the Trustee a certificate to the effect that immediately after
giving pro forma effect to such dividends or advances the Company will have
Available Liquidity in excess of $350 million and (D) such dividends or advances
shall be excluded from the calculation of the amount of Restricted Payments; or
(6) other Restricted Payments in an aggregate amount not to exceed $25
million; provided, however, that such Restricted Payments shall be excluded from
the calculation of the amount of Restricted Payments.
LIMITATION ON RESTRICTIONS ON DISTRIBUTIONS FROM RESTRICTED SUBSIDIARIES
The Company will not, and will not permit any Restricted Subsidiary to,
create or otherwise cause or permit to exist or become effective any consensual
encumbrance or restriction on the ability of any Restricted Subsidiary to (a)
pay dividends or make any other distributions on its Capital Stock to the
Company or a Restricted Subsidiary or pay any Indebtedness owed to the Company,
(b) make any loans or advances to the Company or (c) transfer any of its
property or assets to the Company, except:
(1) with respect to clauses (a), (b) and (c),
(i) any encumbrance or restriction pursuant to an agreement in effect at or
entered into on the Issue Date, including the Credit Agreements (other than the
New Credit Agreement);
(ii) (A) any encumbrance or restriction pursuant to the New Credit
Agreement that is substantially similar to, and no less favorable to the
Exchange Noteholders than, encumbrances or restrictions in effect at or entered
into on the Issue Date pursuant to the Credit Agreements (other than the New
Credit Agreement), (B) any encumbrance or restriction on the ability of the
Pledged Entities to pay dividends, make distributions, loans or advances, or
transfer assets to the Company imposed pursuant to the New Credit Agreement and
(C) Liens on the Capital Stock of the Pledged Entities imposed pursuant to the
New Credit Agreement;
(iii) any encumbrance or restriction with respect to a Restricted
Subsidiary pursuant to an agreement relating to any Indebtedness Incurred by
such Restricted Subsidiary on or prior to the date on which such Restricted
Subsidiary was acquired by the Company (other than Indebtedness Incurred as
consideration in, or to provide all or any portion of the funds or credit
support utilized to consummate, the transaction or series of related
transactions pursuant to which such Restricted Subsidiary became a Restricted
Subsidiary or was acquired by the Company) and outstanding on such date;
(iv) any encumbrance or restriction pursuant to an agreement effecting a
Refinancing of Indebtedness Incurred pursuant to an agreement referred to in
clause (i), (ii) or (iii) of clause (1) of this covenant or this clause (iv) or
contained in any amendment to an agreement referred to in clause (i), (ii) or
(iii) of clause (1) of this covenant or this clause (iv); provided, however,
that the encumbrances and restrictions with respect to such Restricted
Subsidiary contained in any such refinancing agreement or amendment are no less
favorable to the Exchange Noteholders than encumbrances and restrictions with
respect to such Restricted Subsidiary contained in such predecessor agreements;
(v) any encumbrance or restriction with respect to a Restricted Subsidiary
imposed pursuant to an agreement entered into for the sale or disposition of all
or substantially all the Capital Stock or assets of such Restricted Subsidiary
pending the closing of such sale or disposition;
(vi) any encumbrance or restriction arising under any applicable law, rule,
regulation or order;
(vii) any encumbrance or restriction pursuant to any merger agreement,
stock purchase agreement, asset sale agreement or similar agreement limiting the
transfer of properties and assets subject to such agreement or distributions of
assets subject to such agreement pending consummation of the transactions
contemplated thereby;
(viii) any encumbrance or restriction applicable to a Receivables
Subsidiary; and
(2) with respect to clause (c) only,
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(A) any encumbrance or restriction consisting of customary nonassignment
provisions in leases governing leasehold interests to the extent such provisions
restrict the transfer of the lease or the property leased thereunder; and
(B) any encumbrance or restriction contained in security agreements or
mortgages securing Indebtedness of a Restricted Subsidiary to the extent such
encumbrance or restriction restricts the transfer of the property subject to
such security agreements or mortgages.
LIMITATION ON SALES OF ASSETS AND SUBSIDIARY STOCK
(a) The Company will not, and will not permit any Restricted Subsidiary to,
directly or indirectly, consummate any Asset Disposition unless:
(1) the Company or such Restricted Subsidiary receives consideration at the
time of such Asset Disposition at least equal to the fair market value
(including as to the value of all non-cash consideration), as determined in good
faith by the Board of Directors of the Company, of the shares and assets subject
to such Asset Disposition;
(2) other than with respect to any assets contributed by the Company or a
Restricted Subsidiary to a joint venture formed by the Company or such
Restricted Subsidiary, respectively, at least 75% of the consideration thereof
received by the Company or such Restricted Subsidiary is in the form of cash or
cash equivalents; provided, however, that the 75% limitation also will not apply
to any disposition of assets in exchange for assets used in a Related Business,
or a combination of such assets and cash or cash equivalents, in each case
having a fair market value comparable to the fair market value of the assets
disposed of by the Company or a Restricted Subsidiary; provided further,
however, that in any such exchange of the Company's or a Restricted Subsidiary's
assets with a fair market value in excess of $20 million, the Company must
obtain an opinion or report from an Independent Qualified Party confirming that
the assets, and cash and cash equivalents, if any, received in such exchange
have a fair market value at least equal to the assets so exchanged; and
(3) an amount equal to 100% of the Net Available Cash from such Asset
Disposition is applied by the Company (or such Restricted Subsidiary, as the
case may be)
(A) first, to the extent the Company elects (or is required by the terms of
any Indebtedness), to prepay, repay, redeem or purchase Senior Indebtedness of
the Company or Indebtedness (other than any Disqualified Stock) of a Wholly
Owned Subsidiary (in each case other than Indebtedness owed to the Company or an
Affiliate of the Company) within one year from the later of the date of such
Asset Disposition or the receipt of such Net Available Cash;
(B) second, to the extent of the balance of such Net Available Cash after
application in accordance with clause (A), to the extent the Company elects, to
acquire Additional Assets within one year from the later of the date of such
Asset Disposition or the receipt of such Net Available Cash; and
(C) third, to the extent of the balance of such Net Available Cash after
application in accordance with clauses (A) and (B), to make an offer to the
holders of the Exchange Notes (and to holders of other Senior Indebtedness of
the Company designated by the Company) to purchase Exchange Notes (and such
other Senior Indebtedness of the Company) pursuant to and subject to the
conditions contained in the Indenture;
provided, however, that in connection with any prepayment, repayment or
purchase of Indebtedness pursuant to clause (A) or (C) above, the Company or
such Restricted Subsidiary shall permanently retire such Indebtedness and shall
cause the related loan commitment (if any) to be permanently reduced in an
amount equal to the principal amount so prepaid, repaid or purchased.
Notwithstanding the foregoing provisions of this covenant, the Company and
the Restricted Subsidiaries will not be required to apply any Net Available Cash
in accordance with this covenant except to the extent that the aggregate Net
Available Cash from all Asset Dispositions which is not applied in accordance
with this covenant exceeds $20 million. Pending application of Net Available
Cash pursuant to this covenant, such Net Available Cash shall be invested in
Temporary Cash Investments or applied to temporarily reduce revolving credit
indebtedness.
For the purposes of this covenant, the following are deemed to be cash or
cash equivalents:
(1) the assumption of Indebtedness of the Company (other than obligations
in respect of Disqualified Stock of the Company) or any Restricted Subsidiary
and the release of the Company or such Restricted Subsidiary from all liability
on such Indebtedness in connection with such Asset Disposition; and
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(2) securities received by the Company or any Restricted Subsidiary from
the transferee that are promptly converted by the Company or such Restricted
Subsidiary into cash, to the extent of cash received in that conversion.
(b) In the event of an Asset Disposition that requires the purchase of
Exchange Notes (and other Senior Indebtedness of the Company) pursuant to clause
(a)(3)(C) above, the Company will purchase Exchange Notes tendered pursuant to
an offer by the Company for the Exchange Notes (and such other Senior
Indebtedness) at a purchase price of 100% of their principal amount (or, in the
event such other Senior Indebtedness of the Company was issued with significant
original issue discount, 100% of the accreted value thereof) without premium,
plus accrued but unpaid interest (or, in respect of such other Senior
Indebtedness of the Company, such lesser price, if any, as may be provided for
by the terms of such Senior Indebtedness) in accordance with the procedures
(including prorating in the event of oversubscription) set forth in the
Indenture. If the aggregate purchase price of the securities tendered exceeds
the Net Available Cash allotted to their purchase, the Company will select the
securities to be purchased on a pro rata basis but in round denominations, which
in the case of the Exchange Notes will be denominations of $1,000 principal
amount or multiples thereof. The Company shall not be required to make such an
offer to purchase Exchange Notes (and other Senior Indebtedness of the Company)
pursuant to this covenant if the Net Available Cash available therefor is less
than $20 million (which lesser amount shall be carried forward for purposes of
determining whether such an offer is required with respect to the Net Available
Cash from any subsequent Asset Disposition). Upon completion of such an offer to
purchase, Net Available Cash will be deemed to be reduced by the aggregate
amount of such offer.
(c) The Company will comply, to the extent applicable, with the
requirements of Section 14(e) of the Exchange Act and any other securities laws
or regulations in connection with the repurchase of Exchange Notes pursuant to
this covenant. To the extent that the provisions of any securities laws or
regulations conflict with provisions of this covenant, the Company will comply
with the applicable securities laws and regulations and will not be deemed to
have breached its obligations under this covenant by virtue of its compliance
with such securities laws or regulations.
LIMITATION ON AFFILIATE TRANSACTIONS
(a) The Company will not, and will not permit any Restricted Subsidiary to,
enter into or permit to exist any transaction (including the purchase, sale,
lease or exchange of any property, employee compensation arrangements or the
rendering of any service) with, or for the benefit of, any Affiliate of the
Company (an "Affiliate Transaction") unless:
(1) the terms of the Affiliate Transaction are no less favorable to the
Company or such Restricted Subsidiary than those that could be obtained at the
time of the Affiliate Transaction in arm's-length dealings with a Person who is
not an Affiliate;
(2) if such Affiliate Transaction involves an amount in excess of $10
million, the terms of the Affiliate Transaction are set forth in writing and a
majority of the directors of the Company disinterested with respect to such
Affiliate Transaction have determined in good faith that the criteria set forth
in clause (1) are satisfied and have approved the relevant Affiliate Transaction
as evidenced by a resolution of the Board of Directors; provided, however, that
in the event that at the time such Affiliate Transaction is entered into or
permitted to exist no director of the Company is disinterested with respect to
such Affiliate Transaction, the Board of Directors of the Company shall have
received with respect to such Affiliate Transaction the opinion referred to in
paragraph (3) below; and
(3) if such Affiliate Transaction involves an amount in excess of $20
million, the Board of Directors of the Company shall also have received a
written opinion from an Independent Qualified Party to the effect that such
Affiliate Transaction is fair, from a financial standpoint, to the Company and
its Restricted Subsidiaries or is not less favorable to the Company and its
Restricted Subsidiaries than could reasonably be expected to be obtained at the
time in an arm's-length transaction with a Person who was not an Affiliate.
(b) The provisions of the preceding paragraph (a) will not prohibit:
(1) any Investment (other than a Permitted Investment) or other Restricted
Payment, in each case permitted to be made pursuant to the covenant described
under "-- Limitation on Restricted Payments;"
(2) any issuance of securities, or other payments, awards or grants in
cash, securities or otherwise pursuant to, or the funding of, employment
arrangements, stock options and stock ownership plans approved by the Board of
Directors of the Company;
(3) loans or advances to employees in the ordinary course of business in
accordance with the past practices of the Company or its Restricted
Subsidiaries, but in any event not to exceed $5 million in the aggregate
outstanding at any one time;
(4) the payment of reasonable fees to directors of the Company and its
Restricted Subsidiaries who are not employees of the Company or its Restricted
Subsidiaries;
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(5) any transaction with a Restricted Subsidiary or joint venture or
similar entity which would constitute an Affiliate Transaction solely because
the Company or a Restricted Subsidiary owns an equity interest in or otherwise
controls such Restricted Subsidiary, joint venture or similar entity;
(6) the issuance or sale of any Capital Stock (other than Disqualified
Stock) of the Company;
(7) any agreement in effect on the Issue Date and described in the offering
circular under which the outstanding notes were issued or in any of the SEC
filings of the Company incorporated by reference in the offering circular under
which the outstanding notes were issued or any amendments, renewals, extensions
or substitutions of any such agreement (so long as such amendments, renewals,
extensions or substitutions are not less favorable to the Company or the
Restricted Subsidiaries) and the transactions evidenced thereby;
(8) any transactions with the Permitted Holder or any of its Affiliates
involving the purchase or sale of hydrocarbons, or refined products therefrom,
in the ordinary course of business, so long as such transactions are priced
based on industry accepted benchmark prices and the pricing of such transactions
is no worse to the Company or any Restricted Subsidiary, as applicable, than the
pricing of comparable transactions with unrelated third parties; and
(9) any Intercompany Trade Arrangements.
LIMITATION ON LIENS
The Company will not, and will not permit any Restricted Subsidiary to,
directly or indirectly, Incur or permit to exist any Lien (the "Initial Lien")
of any nature whatsoever on any of its properties (including Capital Stock of a
Restricted Subsidiary), whether owned at the Issue Date or thereafter acquired,
securing any Indebtedness, other than Permitted Liens, without effectively
providing that the Exchange Notes shall be secured equally and ratably with (or
prior to) the obligations so secured for so long as such obligations are so
secured; provided, however, that the Company or any Restricted Subsidiary will
be entitled to Incur other Liens to secure Indebtedness as long as the amount of
outstanding Indebtedness secured by Liens Incurred pursuant to this proviso does
not exceed 5% of Consolidated Net Tangible Assets, as determined based on the
consolidated balance sheet of the Company as of the end of the most recent
fiscal quarter ending at least 45 days prior thereto; provided, further,
however, that the aggregate amount of outstanding Indebtedness secured by Liens
on assets of Restricted Subsidiaries pursuant to the foregoing proviso shall in
no event exceed the greater of (A) $125 million and (B) 5% of Consolidated Net
Worth.
Any Lien created for the benefit of the Holders of the Notes pursuant to
the preceding sentence shall provide by its terms that such Lien shall be
automatically and unconditionally released and discharged upon the release and
discharge of the Initial Lien.
LIMITATION ON SALE/LEASEBACK TRANSACTIONS
The Company will not, and will not permit any Restricted Subsidiary to,
enter into any Sale/Leaseback Transaction with respect to any property unless:
(1) the Company or such Restricted Subsidiary would be entitled to (A)
Incur Indebtedness in an amount equal to the Attributable Debt with respect to
such Sale/Leaseback Transaction pursuant to the covenant described under "--
Limitation on Indebtedness" and (B) create a Lien on such property securing such
Attributable Debt without equally and ratably securing the Exchange Notes
pursuant to the covenant described under "-- Limitation on Liens;"
(2) the net proceeds received by the Company or any Restricted Subsidiary
in connection with such Sale/Leaseback Transaction are at least equal to the
fair value (as determined by the Board of Directors of the Company) of such
property; and
(3) the Company applies the proceeds of such transaction in compliance with
the covenant described under "-- Limitation on Sales of Assets and Subsidiary
Stock."
MERGER AND CONSOLIDATION
The Company will not consolidate with or merge with or into, or convey,
transfer or lease, in one transaction or a series of transactions, directly or
indirectly, all or substantially all its assets to, any Person, unless:
(1) the resulting, surviving or transferee Person (the "Successor Company")
shall be a Person organized and existing under the laws of the United States of
America, any State thereof or the District of Columbia and the Successor Company
(if not the Company)
83
shall expressly assume, by an indenture supplemental thereto, executed and
delivered to the Trustee, in form satisfactory to the Trustee, all the
obligations of the Company under the Exchange Notes and the Indenture;
(2) immediately after giving effect to such transaction (and treating any
Indebtedness which becomes an obligation of the Successor Company or any
Subsidiary as a result of such transaction as having been Incurred by such
Successor Company or such Subsidiary at the time of such transaction), no
Default shall have occurred and be continuing;
(3) immediately after giving pro forma effect to such transaction, the
Successor Company would be able to Incur an additional $1.00 of Indebtedness
pursuant to paragraph (a) of the covenant described under "-- Limitation on
Indebtedness;" and
(4) immediately after giving pro forma effect to such transaction, the
Successor Company shall have Consolidated Net Worth in an amount that is not
less than the Consolidated Net Worth of the Company immediately prior to such
transaction;
provided, however, that clauses (3) and (4) will not be applicable to (A) a
Restricted Subsidiary consolidating with, merging into or transferring all or
part of its properties and assets to the Company or (B) the Company merging with
an Affiliate of the Company solely for the purpose and with the sole effect of
reincorporating the Company in another jurisdiction.
For purposes of this covenant, the sale, lease, conveyance, assignment,
transfer or other disposition of all or substantially all of the properties and
assets of one or more Subsidiaries of the Company, which properties and assets,
if held by the Company instead of such Subsidiaries, would constitute all or
substantially all of the properties and assets of the Company on a consolidated
basis, shall be deemed to be the transfer of all or substantially all of the
properties and assets of the Company.
The Successor Company will be the successor to the Company and shall
succeed to, and be substituted for, and may exercise every right and power of,
the Company under the Indenture, and the predecessor Company, except in the case
of a lease, shall be released from the obligation to pay the principal of and
interest on the Notes.
LIMITATION ON ISSUANCE OF GUARANTEES OF INDEBTEDNESS
The Company will not permit any of its Restricted Subsidiaries, directly or
indirectly, to Guarantee or create any Lien to secure the payment of any
Indebtedness of the Company or any other Restricted Subsidiary unless such
Restricted Subsidiary simultaneously executes and delivers a supplemental
indenture to the Indenture providing for the Guarantee or security of the
payment of the Exchange Notes by such Restricted Subsidiary; provided, however,
that the following Guarantees and Liens will not require a Restricted Subsidiary
to execute and deliver such a supplemental indenture: (i) any Guarantee by any
Pledged Entity of Indebtedness Incurred under the New Credit Agreement or (ii)
any Lien created by any Restricted Subsidiary to secure Indebtedness Incurred
pursuant to clause (b)(1) or (b)(3) under "-- Limitation on Indebtedness." If
the Indebtedness to be Guaranteed or secured is subordinated to the Notes, the
Guarantee or security of such Indebtedness will be subordinated to the Guarantee
or security of the Notes to the same extent as the Indebtedness to be Guaranteed
or secured is subordinated to the Notes. Notwithstanding the foregoing, any such
Guarantee or security by a Restricted Subsidiary of the Notes will provide by
its terms that it will be automatically and unconditionally released and
discharged upon either:
(1) the release or discharge of such Guarantee or security of payment of
such other Indebtedness, except a discharge by or as a result of payment under
such Guarantee or security,
(2) any sale (including by way of merger or consolidation), exchange or
transfer, to any Person not an Affiliate of ours, of all of the Capital Stock
owned by the Company and its Restricted Subsidiaries of, or all or substantially
all the assets of, such Restricted Subsidiary, which sale, exchange or transfer
is made in compliance with the applicable provisions of the Indenture, or
(3) the designation by the Company of such Restricted Subsidiary as an
Unrestricted Subsidiary in accordance with the terms of the Indenture.
BUSINESS ACTIVITIES OF PLEDGED ENTITIES
So long as there are Liens on the equity interests of the Pledged Entities
to secure, or the Pledged Entities have otherwise secured, Indebtedness Incurred
pursuant to clause (b)(2) under "-- Limitations on Indebtedness," the Company
shall not permit any of the Pledged Entities to engage in any business or
activity other than the ownership, directly or indirectly, of, in the case of
CITGO Pipeline I, the Company's equity interests in the Colonial Pipeline, and
in the case of CITGO Pipeline II, the Company's equity interests in the Explorer
Pipeline and, in each case, activities incidental thereto. So long as there are
Liens on the equity interests of the Pledged Entities to secure, or the Pledged
Entities have otherwise secured, Indebtedness Incurred pursuant to clause (b)(2)
under "-- Limitations on Indebtedness," the Company shall not permit the Pledged
Entities to own or acquire any assets (other than, in case of
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CITGO Pipeline I, all the equity interests in the Colonial Pipeline and in the
case of CITGO Pipeline II, all the equity interests in the Explorer Pipeline
and, in each case, cash incidental to their permitted activities).
SEC REPORTS
Notwithstanding that the Company may not be subject to the reporting
requirements of Section 13 or 15(d) of the Exchange Act, the Company will file
with the SEC (to the extent the SEC will accept such filings) and provide the
Trustee and Exchange Noteholders 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 other reports to be so filed and provided at the
times specified for the filings of such information, documents and reports under
such Sections.
At any time that any of the Company's Subsidiaries are Unrestricted
Subsidiaries, then the quarterly and annual financial information required by
the preceding paragraph will include a reasonably detailed presentation, either
on the face of the financial statements or in the footnotes thereto, and in
"Management's Discussion and Analysis of Financial Condition and Results of
Operations," of the financial condition and results of operations of the Company
and its Restricted Subsidiaries separate from the financial condition and
results of operations of the Unrestricted Subsidiaries of the Company.
CERTAIN INVESTMENT GRADE COVENANTS
If an Investment Grade Rating Event occurs, each of the covenants (except
for clause (1) of "-- Merger and Consolidation" and "-- SEC Reports") described
above under "-- Certain Covenants" will cease to apply to us and our Restricted
Subsidiaries. Instead, the Indenture contains the following covenants, each of
which will apply to us only upon and after the occurrence of an Investment Grade
Rating Event.
RESTRICTIONS ON SECURED INDEBTEDNESS
If the Company or any Restricted Subsidiary Incurs any Indebtedness secured
by a Lien (other than a Permitted Lien) on any Principal Property or on any
share of stock or Indebtedness of a Restricted Subsidiary, the Company or such
Restricted Subsidiary will secure the Exchange Notes equally and ratable with
(or, at the Company's option, prior to) such secured Indebtedness so long as
such Indebtedness is so secured, unless the aggregate amount of all such secured
Indebtedness, together with all Attributable Debt of the Company and the
Restricted Subsidiaries with respect to any Sale/Leaseback Transactions
involving Principal Properties (with the exception of such transactions which
are excluded as described in clauses (1) through (5) under "-- Restrictions on
Sale/Leaseback Transactions" below), would not exceed 10% of Consolidated Net
Tangible Assets.
RESTRICTIONS ON SALE/LEASEBACK TRANSACTIONS
The Company will not, and will not permit any Restricted Subsidiary to,
enter into any Sale/Leaseback Transaction involving any Principal Property,
unless the aggregate amount of all Attributable Debt with respect to such
transaction plus all secured Indebtedness of the Company and the Restricted
Subsidiaries (with the exception of Indebtedness secured by Permitted Liens)
would not exceed 10% of Consolidated Net Tangible Assets. This restriction shall
not apply to, and there shall be excluded from Attributable Debt in any
computation under such restriction, any Sale/Leaseback Transaction if:
(1) the lease is for a period, including renewal rights, not in excess of
three years;
(2) the sale of the Principal Property is made within 270 days after its
acquisition, construction or improvements;
(3) the lease secures or relates to industrial revenue or pollution control
bonds;
(4) the transaction is between us and a Restricted Subsidiary; or
(5) the Company, within 270 days after the sale is completed, applies to
the retirement of its Indebtedness or that of a Restricted Subsidiary, or to the
purchase of other property which will constitute a Principal Property, an amount
not less than the greater of:
(A) the net proceeds of the sale of the Principal Property leased or
(B) the fair market value (as determined by us in good faith) of the
Principal Property leased.
The amount to be applied to the retirement of Indebtedness shall be reduced
by:
85
(i) the principal amount of any of the Company's debentures or notes
(including the Exchange Notes) or those of a Restricted Subsidiary surrendered
within 270 days after such sale to the applicable trustee for retirement and
cancelation;
(ii) the principal amount of Indebtedness, other than the items referred to
in the preceding clause (i), voluntarily retired by the Company or a Restricted
Subsidiary within 270 days after such sale; and
(iii) associated transaction expenses.
EVENTS OF DEFAULT
Each of the following is an Event of Default:
(1) a default in the payment of interest on the Notes when due, continued
for 30 days;
(2) a default in the payment of principal of any Note when due at its
Stated Maturity, upon optional redemption, upon required purchase, upon
declaration of acceleration or otherwise;
(3) the failure by the Company to comply with its obligations under "--
Certain Covenants -- Merger and Consolidation" above;
(4) the failure by the Company to comply for 30 days after notice with any
of its obligations, if then applicable, in the covenants described above under
"-- Change of Control" (other than a failure to purchase Exchange Notes) or
under "-- Certain Covenants" under "-- Limitation on Indebtedness," "--
Limitation on Restricted Payments," "-- Limitation on Restrictions on
Distributions from Restricted Subsidiaries," "-- Limitation on Sales of Assets
and Subsidiary Stock" (other than a failure to purchase Exchange Notes), "--
Limitation on Affiliate Transactions," "-- Limitation on Liens," "-- Limitation
on Sale/Leaseback Transactions," "-- Limitation on Issuance of Guarantees of
Indebtedness," "-- Business Activities of Pledged Entities" or "-- SEC Reports"
or under "-- Certain Investment Grade Covenants;"
(5) the failure by the Company or any Subsidiary Guarantor to comply for 60
days after notice with its other agreements contained in the Indenture;
(6) Indebtedness of the Company or any Significant Subsidiary is not paid
within any applicable grace period after final maturity or is accelerated by the
holders thereof because of a default and the total amount of such Indebtedness
unpaid or accelerated exceeds $35 million (the "cross acceleration provision");
(7) certain events of bankruptcy, insolvency or reorganization of the
Company or any Significant Subsidiary (the "bankruptcy provisions");
(8) any judgment or decree for the payment of money in excess of $35
million is entered against the Company or any Significant Subsidiary, remains
outstanding for a period of 60 consecutive days following such judgment and is
not discharged, waived or stayed (the "judgment default provision"); or
(9) any Subsidiary Guaranty ceases to be in full force and effect (other
than in accordance with the terms of the Indenture or such Subsidiary Guaranty)
or any Subsidiary Guarantor denies or disaffirms its obligations under its
Subsidiary Guaranty.
However, a default under clauses (4) and (5) will not constitute an Event of
Default until the Trustee or the Holders of 25% in principal amount of the
outstanding Notes notify the Company in writing of the default and the Company
does not cure such default within the time specified after receipt of such
notice, provided, however, that in the case of a default under clause (4)
constituting a failure to comply with the covenant described under "-- Certain
Covenants -- Limitation on Restricted Payments," the Holders of at least 12.5%
in principal amount of the outstanding Notes may effectuate such written notice.
If an Event of Default occurs and is continuing, the Trustee or the Holders
of at least 25% in principal amount of the outstanding Notes may declare the
principal of and accrued but unpaid interest on all the Notes to be due and
payable, provided, however, that, if such Event of Default results from a
failure to comply with the covenant described under "-- Certain Covenants --
Limitation on Restricted Payments," the Holders of at least 12.5% in principal
amount of Notes may make the foregoing declaration. Upon such a declaration,
such principal and interest shall be due and payable immediately. If an Event of
Default relating to certain events of bankruptcy, insolvency or reorganization
of the Company occurs and is continuing, the principal of and interest on all
the Notes will ipso facto become and be immediately due and payable without any
declaration or other act on the part of the Trustee or any holders of the Notes.
Under certain circumstances, the Holders of a majority in principal amount of
the Notes may rescind any such acceleration with respect to the Notes and its
consequences.
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Subject to the provisions of the Indenture relating to the duties of the
Trustee, in case an Event of Default occurs and is continuing, the Trustee will
be under no obligation to exercise any of the rights or powers under the
Indenture at the request or direction of any of the Holders of the Notes unless
such Holders have offered to the Trustee reasonable indemnity or security
against any loss, liability or expense. Except to enforce the right to receive
payment of principal, premium (if any) or interest when due, no Holder of a Note
may pursue any remedy with respect to the Indenture or the Notes unless:
(1) such Holder has previously given the Trustee notice that an Event of
Default is continuing;
(2) Holders of at least 25% (or 12.5% in the case of a failure to comply
with the covenant described under "--Certain Covenants -- Limitation on
Restricted Payments") in principal amount of the Notes have requested the
Trustee to pursue the remedy;
(3) such Holders have offered the Trustee reasonable security or indemnity
against any loss, liability or expense;
(4) the Trustee has not complied with such request within 60 days after the
receipt thereof and the offer of security or indemnity; and
(5) holders of a majority in principal amount of the Notes have not given
the Trustee a direction inconsistent with such request within such 60-day
period.
Subject to certain restrictions, the Holders of a majority in principal amount
of Notes are given the right to direct the time, method and place of conducting
any proceeding for any remedy available to the Trustee or of exercising any
trust or power conferred on the Trustee. The Trustee, however, may refuse to
follow any direction that conflicts with law or the Indenture or that the
Trustee determines is unduly prejudicial to the rights of any other Holder of a
Note or that would involve the Trustee in personal liability.
If a Default occurs, is continuing and is known to the Trustee, the Trustee
must mail to each Holder of the Notes notice of the Default within 90 days after
it occurs, provided, however, that, if such Default constitutes a failure to
comply with the covenant described under "-- Certain Covenants -- Limitation on
Restricted Payments," the Trustee must mail to each Holder of the Notes notice
of such Default within 40 days after it occurs. Except in the case of a Default
in the payment of principal of or interest on any Note, the Trustee may withhold
notice if and so long as a committee of its Trust Officers determines that
withholding notice is not opposed to the interest of the holders of the Notes.
In addition, we are required to deliver to the Trustee, within 120 days after
the end of each fiscal year, a certificate indicating whether the signers
thereof know of any Default that occurred during the previous year. We are
required to deliver to the Trustee, within 30 days after the occurrence thereof,
written notice of any event which would constitute certain Defaults, their
status and what action we are taking or propose to take in respect thereof.
AMENDMENTS AND WAIVERS
Subject to certain exceptions, the Indenture may be amended with the
consent of the holders of a majority in principal amount of the Notes then
outstanding (including consents obtained in connection with a tender offer or
exchange for the Notes) and any past default or compliance with any provisions
may also be waived with the consent of the Holders of a majority in principal
amount of the Notes then outstanding. However, without the consent of each
holder of an outstanding Note affected thereby, an amendment or waiver may not,
among other things:
(1) reduce the amount of Notes whose holders must consent to an amendment;
(2) reduce the rate of or extend the time for payment of interest on any
Note;
(3) reduce the principal of or change the Stated Maturity of any Note;
(4) change the provisions applicable to the redemption of any Note as
described under "-- Optional Redemption" above;
(5) make any Note payable in money other than that stated in the Note;
(6) impair the right of any Holder of the Notes to receive payment of
principal of and interest on such Holder's Notes on or after the due dates
therefor or to institute suit for the enforcement of any payment on or with
respect to such holder's Exchange Notes;
(7) make any change in the amendment provisions which require each Holder's
consent or in the waiver provisions;
(8) make any change in the ranking or priority of any Note that would
adversely affect the Noteholders; or
87
(9) make any change in any Subsidiary Guaranty that would adversely affect
the Noteholders.
Notwithstanding the preceding, without the consent of any Holder of the
Notes, the Company, the Subsidiary Guarantors, if any, and the Trustee may amend
the Indenture:
(1) to cure any ambiguity, omission, defect or inconsistency;
(2) to provide for the assumption by a successor Person of the obligations
of the Company or any Subsidiary Guarantor under the Indenture;
(3) to provide for uncertificated Notes in addition to or in place of
certificated Notes (provided that the uncertificated Notes are issued in
registered form for purposes of Section 163(f) of the Code, or in a manner such
that the uncertificated Notes are described in Section 163(f)(2)(B) of the
Code);
(4) to add Guarantees with respect to the Notes, including Subsidiary
Guaranties, or to secure the Notes;
(5) to add to the covenants of the Company or any Subsidiary Guarantor for
the benefit of the holders of the Notes or to surrender any right or power
conferred upon the Company or any Subsidiary Guarantor;
(6) to make any change that does not adversely affect the rights of any
Holder of the Notes; or
(7) to comply with any requirement of the SEC in connection with the
qualification of the Indenture under the Trust Indenture Act.
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 holders of the Notes 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.
TRANSFER
The Exchange Notes will be issued in registered form and will be
transferable only upon the surrender of the Exchange Notes being transferred for
registration of transfer. We may require payment of a sum sufficient to cover
any tax, assessment or other governmental charge payable in connection with
certain transfers and exchanges.
DEFEASANCE
At any time, we may terminate all our obligations under the Exchange Notes
and the Indenture ("legal defeasance"), except for certain obligations,
including those respecting the defeasance trust and obligations to register the
transfer of the Exchange Notes, to replace mutilated, destroyed, lost or stolen
Exchange Notes and to maintain a registrar and paying agent in respect of the
Exchange Notes.
In addition, at any time we may terminate our obligations under "-- Change
of Control" and under the covenants described under "-- Certain Covenants"
(other than the covenant described under "-- Merger and Consolidation") and "--
Certain Investment Grade Covenants," the operation of the cross acceleration
provision, the bankruptcy provisions with respect to Significant Subsidiaries
and the judgment default provision described under "-- Events of Default" above
and the limitations contained in clauses (3) and (4) under "-- Certain Covenants
- -- Merger and Consolidation" above ("covenant defeasance").
We may exercise our legal defeasance option notwithstanding our prior
exercise of our covenant defeasance option. If we exercise our legal defeasance
option, payment of the Exchange Notes may not be accelerated because of an Event
of Default with respect thereto. If we exercise our covenant defeasance option,
payment of the Exchange Notes may not be accelerated because of an Event of
Default specified in clause (4), (6), (7) (with respect only to Significant
Subsidiaries) or (8) under "-- Events of Default" above or because of the
failure of the Company to comply with clause (3) or (4) under "-- Certain
Covenants -- Merger and Consolidation" above.
In order to exercise either of our defeasance options, we must irrevocably
deposit in trust (the "defeasance trust") with the Trustee money or U.S.
Government Obligations for the payment of principal and interest on the Exchange
Notes to redemption or maturity, as the case may be, and must comply with
certain other conditions, including delivery to the Trustee of an Opinion of
Counsel to the
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effect that holders of the Exchange Notes will not recognize income, gain or
loss for Federal income tax purposes as a result of such deposit and defeasance
and will be subject to Federal income tax on the same amounts and in the same
manner and at the same times as would have been the case if such deposit and
defeasance had not occurred (and, in the case of legal defeasance only, such
Opinion of Counsel must be based on a ruling of the Internal Revenue Service or
other change in applicable Federal income tax law).
CONCERNING THE TRUSTEE
The Bank of New York is to be the Trustee under the Indenture. We have
appointed The Bank of New York as Registrar and Paying Agent with regard to the
Exchange Notes.
The Indenture contains certain limitations on the rights of the Trustee,
should it become a creditor of the Company, to obtain payment of claims in
certain cases, or to realize on certain property received in respect of any such
claim as security or otherwise. The Trustee will be permitted to engage in other
transactions; provided, however, if it acquires any conflicting interest it must
either eliminate such conflict within 90 days, apply to the SEC for permission
to continue or resign.
The Holders of a majority in principal amount of the outstanding Notes will
have the right to direct the time, method and place of conducting any proceeding
for exercising any remedy available to the Trustee, subject to certain
exceptions. If an Event of Default occurs (and is not cured), the Trustee will
be required, in the exercise of its power, to use the degree of care of a
prudent man in the conduct of his own affairs. Subject to such provisions, the
Trustee will be under no obligation to exercise any of its rights or powers
under the Indenture at the request of any Holder of Notes, unless such Holder
shall have offered to the Trustee security and indemnity satisfactory to it
against any loss, liability or expense and then only to the extent required by
the terms of the Indenture.
NO PERSONAL LIABILITY OF DIRECTORS, OFFICERS, EMPLOYEES AND STOCKHOLDERS
No director, officer, employee, incorporator or stockholder of the Company
will have any liability for any obligations of the Company under the Exchange
Notes or the Indenture or for any claim based on, in respect of, or by reason of
such obligations or their creation. Each Holder of the Exchange Notes by
accepting an Exchange Note waives and releases all such liability. The waiver
and release are part of the consideration for issuance of the Exchange Notes.
Such waiver and release may not be effective to waive liabilities under the U.S.
Federal securities laws, and it is the view of the SEC that such a waiver is
against public policy.
GOVERNING LAW
The Indenture and the Exchange Notes will be governed by, and construed in
accordance with, the laws of the State of New York without giving effect to
applicable principles of conflicts of law to the extent that the application of
the law of another jurisdiction would be required thereby.
CERTAIN DEFINITIONS
"Additional Assets" means:
(1) any property, plant or equipment used in a Related Business;
(2) the Capital Stock of a Person that becomes a Restricted Subsidiary as a
result of the acquisition of such Capital Stock by the Company or another
Restricted Subsidiary; or
(3) Capital Stock constituting a minority interest in any Person that at
such time is a Restricted Subsidiary;
provided, however, that any such Restricted Subsidiary described in clause (2)
or (3) above is primarily engaged in a Related Business.
"Affiliate" of any specified Person means any other Person, directly or
indirectly, controlling or controlled by or under direct or indirect common
control with such specified Person. For the purposes of this definition,
"control" when used with respect to any Person means the power to direct the
management and policies of such Person, directly or indirectly, whether through
the ownership of voting securities, by contract or otherwise; and the terms
"controlling" and "controlled" have meanings correlative to the foregoing. For
purposes of the covenants described under "-- Certain Covenants -- Limitation on
Restricted Payments," "-- Certain Covenants -- Limitation on Affiliate
Transactions" and "-- Certain Covenants -- Limitation on Sales of Assets and
Subsidiary Stock" only, "Affiliate" shall also mean any beneficial owner of
Capital Stock representing 5% or more of the total voting power of the Voting
Stock (on a fully diluted basis) of the Company or of rights or warrants to
purchase such Capital Stock (whether or not currently exercisable) and any
Person who would be an Affiliate of any such beneficial owner pursuant to the
first sentence hereof.
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"Asset Disposition" means any sale, lease, transfer or other disposition by
the Company or any Restricted Subsidiary, including any disposition by means of
a merger, consolidation or similar transaction (each referred to for the
purposes of this definition as a "disposition"), of:
(1) any shares of Capital Stock, or other ownership interests, of a
Restricted Subsidiary (other than directors' qualifying shares or shares
required by applicable law to be held by a Person other than the Company or a
Restricted Subsidiary);
(2) substantially all the assets of any division or line of business of the
Company or any Restricted Subsidiary; or
(3) any other assets of the Company or any Restricted Subsidiary outside of
the ordinary course of business of the Company or such Restricted Subsidiary
other than, in the case of clauses (1), (2) and (3) above,
(A) a disposition by a Restricted Subsidiary to the Company or by the
Company or a Restricted Subsidiary to a Wholly Owned Subsidiary;
(B) for purposes of the covenant described under "-- Certain Covenants --
Limitation on Sales of Assets and Subsidiary Stock" only, (x) a disposition that
constitutes a Restricted Payment (or would constitute a Restricted Payment but
for the exclusions from the definition thereof) and that is not prohibited by
the covenant described under "-- Certain Covenants -- Limitation on Restricted
Payments" and (y) a disposition of all or substantially all the assets of the
Company in accordance with the covenant described under "-- Certain Covenants --
Merger and Consolidation;"
(C) a disposition, whether in a single transaction or a series of related
transactions, of assets with a fair market value of less than $10 million;
(D) sales pursuant to a Qualified Receivables Transaction of accounts
receivable and related assets of the type specified in the definition of
"Qualified Receivables Transaction" to a Receivables Subsidiary (in the case of
a sale by the Company or any of its Restricted Subsidiaries) or any other Person
(in the case of a sale by a Receivables Subsidiary), in each case, for the fair
market value thereof, including cash in an amount at least equal to 90% of the
fair market value thereof as determined in accordance with GAAP;
(E) sales by the Company or any Restricted Subsidiary of hydrocarbons or
refined products therefrom that the Company or any Restricted Subsidiary had
previously acquired from the Permitted Holder or any of its Subsidiaries
pursuant to an arrangement between the Company and the Permitted Holder
providing for the resale by the Company or any Restricted Subsidiary of the
Permitted Holder's products for a customary fee;
(F) sales by the Company or any Restricted Subsidiary of inventory at fair
market value for cash consideration to the extent such cash consideration is
applied by the Company or such Restricted Subsidiary within 20 days of such sale
to acquire hydrocarbons or refined products; and
(G) a disposition of cash or Temporary Cash Investments.
"Attributable Debt" in respect of a Sale/Leaseback Transaction means, as at
the time of determination, the present value (discounted at the interest rate
borne by the Exchange Notes, compounded annually) of the total obligations of
the lessee for rental payments during the remaining term of the lease included
in such Sale/Leaseback Transaction (including any period for which such lease
has been extended); provided, however, that if such Sale/Leaseback Transaction
results in a Capital Lease Obligation, the amount of Indebtedness represented
thereby with be determined in accordance with the definition of "Capital Lease
Obligation."
"Available Liquidity" with respect to the Company means, at any time, the
sum of (w) committed lines of credit that may be readily drawn by the Company,
(x) funds readily available to the Company pursuant to an accounts receivable
facility permitted by clause (b)(13) under "-- Certain Covenants -- Limitation
on Indebtedness" and (y) unrestricted cash on the consolidated balance sheet of
the Company held by the Company or any Restricted Subsidiary; provided, however,
that any cash of any Restricted Subsidiary shall be deemed to be unrestricted
for purposes of this definition only to the extent that such Restricted
Subsidiary is not, at the applicable time, subject to any material restrictions,
directly or indirectly, on its ability to dividend or distribute such cash to
the Company.
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"Average Life" means, as of the date of determination, with respect to any
Indebtedness, the quotient obtained by dividing:
(1) the sum of the products of the numbers of years from the date of
determination to the dates of each successive scheduled principal payment of
such Indebtedness or redemption or similar payment with respect to such
Indebtedness multiplied by the amount of such payment by
(2) the sum of all such payments.
"Board of Directors" with respect to a Person means the Board of Directors
of such Person or any committee thereof duly authorized to act on behalf of such
Board.
"Business Day" means each day which is not a Legal Holiday.
"Capital Lease Obligation" means an obligation that is required to be
classified and accounted for as a capital lease for financial reporting purposes
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 of rent or any other amount due under such lease prior to the first
date upon which such lease may be terminated by the lessee without payment of a
penalty. For purposes of the covenant described under "-- Certain Covenants --
Limitation on Liens," a Capital Lease Obligation will be deemed to be secured by
a Lien on the property being leased.
"Capital Stock" of any Person means any and all shares, interests, rights
to purchase, warrants, options, participations or other equivalents of or
interests in (however designated) equity of such Person, including any Preferred
Stock, but excluding any debt securities convertible into such equity.
"CITGO Pipeline I" means CITGO Pipeline Holding I, LLC, a Delaware limited
liability company that holds the Company's equity interests in the Colonial
Pipeline.
"CITGO Pipeline II" means CITGO Pipeline Holding II, LLC, a Delaware
limited liability company that holds the Company's equity interests in the
Explorer Pipeline.
"CITGO Puerto Rico" means CITGO International Puerto Rico Company, a Puerto
Rican civil partnership and an indirect wholly owned subsidiary of the Company.
"CITGO Puerto Rico Credit Agreement" means the 364-day credit agreement
entered into as of May 28, 2002, among CITGO Puerto Rico, the lenders referred
to therein and Mizuho Corporation Bank Limited as Administrative Agent, together
with the related documents thereto (including the revolving loan facility, note
purchase or placement facility, letter of credit facility or other arrangement
for the extension of credit thereunder, any guarantees and security documents),
as amended, extended, renewed, restated, supplemented or otherwise modified (in
whole or in part, and without limitation as to amount, terms, conditions,
covenants and other provisions) from time to time, and any agreement (and
related document) governing Indebtedness Incurred to Refinance, in whole or in
part, the borrowings and commitments then outstanding or permitted to be
outstanding under such credit agreement or a successor credit agreement, whether
by the same or any other lender or group of lenders.
"Code" means the Internal Revenue Code of 1986, as amended.
"Commodity Agreement" means any commodity or raw material futures contract,
commodity or raw materials option, or any other agreement designed to protect
against or manage exposure to fluctuations in commodity or raw materials prices,
other than hydrocarbons.
"Consolidated Coverage Ratio" as of any date of determination means the
ratio of (x) the aggregate amount of EBITDA for the period of the most recent
four consecutive fiscal quarters ending at least 45 days prior to the date of
such determination to (y) Consolidated Interest Expense for such four fiscal
quarters; provided, however, that:
(1) if the Company or any Restricted Subsidiary has Incurred any
Indebtedness since the beginning of such period that remains outstanding or if
the transaction giving rise to the need to calculate the Consolidated Coverage
Ratio is an Incurrence of Indebtedness, or both, EBITDA and Consolidated
Interest Expense for such period shall be calculated after giving effect on a
pro forma basis to such Indebtedness as if such Indebtedness had been Incurred
on the first day of such period;
(2) if the Company or any Restricted Subsidiary has repaid, repurchased,
defeased or otherwise discharged any Indebtedness since the beginning of such
period or if any Indebtedness is to be repaid, repurchased, defeased or
otherwise discharged (in each case other than Indebtedness Incurred under any
revolving credit facility unless such Indebtedness has been permanently repaid
and has not been replaced) on the date of the transaction giving rise to the
need to calculate the Consolidated Coverage Ratio, EBITDA and Consolidated
Interest Expense for such period shall be calculated on a pro forma basis as if
such discharge had occurred on the first
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day of such period and as if the Company or such Restricted Subsidiary had not
earned the interest income actually earned during such period in respect of cash
or Temporary Cash Investments used to repay, repurchase, defease or otherwise
discharge such Indebtedness;
(3) if since the beginning of such period the Company or any Restricted
Subsidiary shall have made any Asset Disposition, EBITDA for such period shall
be reduced by an amount equal to EBITDA (if positive) directly attributable to
the assets which are the subject of such Asset Disposition for such period, or
increased by an amount equal to EBITDA (if negative), directly attributable
thereto for such period and Consolidated Interest Expense for such period shall
be reduced by an amount equal to the Consolidated Interest Expense directly
attributable to any Indebtedness of the Company or any Restricted Subsidiary
repaid, repurchased, defeased or otherwise discharged with respect to the
Company and its continuing Restricted Subsidiaries in connection with such Asset
Disposition for such period (or, if the Capital Stock of any Restricted
Subsidiary is sold, the Consolidated Interest Expense for such period directly
attributable to the Indebtedness of such Restricted Subsidiary to the extent the
Company and its continuing Restricted Subsidiaries are no longer liable for such
Indebtedness after such sale);
(4) if since the beginning of such period the Company or any Restricted
Subsidiary (by merger or otherwise) shall have made a Material Investment in any
Restricted Subsidiary (or any person which becomes a Restricted Subsidiary) or
an acquisition of assets, including any acquisition of assets occurring in
connection with a transaction requiring a calculation to be made hereunder,
which constitutes all or substantially all of an operating unit of a business,
EBITDA and Consolidated Interest Expense for such period shall be calculated
after giving pro forma effect thereto (including the Incurrence of any
Indebtedness) as if such Material Investment or acquisition occurred on the
first day of such period; and
(5) if since the beginning of such period any Person (that subsequently
became a Restricted Subsidiary or was merged with or into the Company or any
Restricted Subsidiary since the beginning of such period) shall have made any
Asset Disposition, any Investment or acquisition of assets that would have
required an adjustment pursuant to clause (3) or (4) above if made by the
Company or a Restricted Subsidiary during such period, EBITDA and Consolidated
Interest Expense for such period shall be calculated after giving pro forma
effect thereto as if such Asset Disposition, Investment or acquisition occurred
on the first day of such period.
For purposes of this definition, whenever pro forma effect is to be given to an
acquisition of assets, the amount of income or earnings relating thereto and the
amount of Consolidated Interest Expense associated with any Indebtedness
Incurred in connection therewith, the pro forma calculations shall be determined
in good faith by a responsible financial or accounting Officer of the Company.
If any Indebtedness bears a floating rate of interest and is being given pro
forma effect, the interest on such Indebtedness shall be calculated as if the
rate in effect on the date of determination had been the applicable rate for the
entire period (taking into account any Interest Rate Agreement applicable to
such Indebtedness if such Interest Rate Agreement has a remaining term in excess
of 12 months).
"Consolidated Interest Expense" means, for any period, the total interest
expense of the Company and its consolidated Restricted Subsidiaries, plus, to
the extent not included in such total interest expense, and to the extent
incurred by the Company or its Restricted Subsidiaries, without duplication:
(1) interest component of Capital Lease Obligations;
(2) amortization of debt discount;
(3) capitalized interest;
(4) non-cash interest expense;
(5) commissions, discounts and other fees and charges owed with respect to
letters of credit and bankers' acceptance financing;
(6) net payments pursuant to Hedging Obligations arising from Interest Rate
Agreements or Currency Agreements;
(7) dividends accrued in respect of all Preferred Stock held by Persons
other than the Company or a Wholly Owned Subsidiary (other than dividends
payable solely in Capital Stock (other than Disqualified Stock) of the Company);
provided, however, that such dividends will be multiplied by a fraction the
numerator of which is one and the denominator of which is one minus the
effective combined tax rate of the issuer of such Preferred Stock (expressed as
a decimal) for such period (as estimated by the Chief Financial Officer of the
Company in good faith); and
(8) interest accruing on any Indebtedness of any other Person to the extent
such Indebtedness is Guaranteed by (or secured by the assets of) the Company or
any Restricted Subsidiary, other than pursuant to Ordinary Course Guarantees.
"Consolidated Net Income" means, for any period, the net income of the
Company and its consolidated Subsidiaries; provided, however, that there shall
not be included in such Consolidated Net Income:
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(1) any net income of any Person (other than the Company) if such Person is
not a Restricted Subsidiary, except that:
(A) subject to the exclusion contained in clause (3) below, the Company's
equity in the net income of any such Person for such period shall be included in
such Consolidated Net Income up to the aggregate amount of cash actually
distributed by such Person during such period to the Company or a Restricted
Subsidiary as a dividend or other distribution (subject, in the case of a
dividend or other distribution paid to a Restricted Subsidiary, to the
limitations contained in clause (2) below) less, for purposes of the covenant
described under "-- Certain Covenants -- Limitation on Restricted Payments"
only, the aggregate amount of Investments in LCR made pursuant to clause (13) of
the definition of "Permitted Investments;" and
(B) the Company's equity in a net loss of any such Person for such period
shall be included in determining such Consolidated Net Income;
(2) any net income of any Restricted Subsidiary if such Restricted
Subsidiary is subject to restrictions, directly or indirectly, on the payment of
dividends or the making of distributions by such Restricted Subsidiary, directly
or indirectly, to the Company, except that:
(A) subject to the exclusion contained in clause (3) below, the Company's
equity in the net income of any such Restricted Subsidiary for such period shall
be included in such Consolidated Net Income up to the aggregate amount of cash
actually distributed by such Restricted Subsidiary during such period to the
Company or another Restricted Subsidiary as a dividend or other distribution
(subject, in the case of a dividend or other distribution paid to another
Restricted Subsidiary, to the limitation contained in this clause); and
(B) the Company's equity in a net loss of any such Restricted Subsidiary
for such period shall be included in determining such Consolidated Net Income;
(3) any gain (or loss) realized upon the sale or other disposition of any
assets of the Company, its consolidated Subsidiaries or any other Person
(including pursuant to any sale-and-leaseback arrangement) which is not sold or
otherwise disposed of in the ordinary course of business and any gain (or loss)
realized upon the sale or other disposition of any Capital Stock of any Person;
(4) extraordinary gains or losses;
(5) the cumulative effect of a change in accounting principles; and
(6) the tax effect of any of the items described in clauses (1) through (5)
above;
in each case, for such period. Notwithstanding the foregoing, for the purposes
of the covenant described under "-- Certain Covenants -- Limitation on
Restricted Payments" only, there shall be excluded from Consolidated Net Income
any repurchases, repayments or redemptions of Investments, proceeds realized on
the sale of Investments or return of capital to the Company or a Restricted
Subsidiary to the extent such repurchases, repayments, redemptions, proceeds or
returns increase the amount of Restricted Payments permitted under such covenant
pursuant to clause (a)(3)(D) thereof.
"Consolidated Net Tangible Assets" as of any date of determination, means
the consolidated total assets of the Company and its Restricted Subsidiaries
determined in accordance with GAAP, less the sum of
(1) all current liabilities and current liability items; and
(2) all goodwill, trade names, trademarks, patents, organization expense,
unamortized debt discount and expense and other similar intangibles properly
classified as intangibles in accordance with GAAP.
"Consolidated Net Worth" means the total of the amounts shown on the
balance sheet of the Company and its consolidated Subsidiaries, determined on a
consolidated basis in accordance with GAAP, as of the end of the most recent
fiscal quarter of the Company ending at least 45 days prior to the taking of any
action for the purpose of which the determination is being made, as the sum of:
(1) the par or stated value of all outstanding Capital Stock of the Company
plus
(2) paid-in capital or capital surplus relating to such Capital Stock plus
(3) any retained earnings or earned surplus
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less (A) any accumulated deficit and (B) any amounts attributable to
Disqualified Stock.
"Credit Agreements" means
(1) the Three-Year Credit Agreement;
(2) the 364-Day Credit Agreement;
(3) the CITGO Puerto Rico Credit Agreement; and
(4) the New Credit Agreement.
"Currency Agreement" means any foreign exchange contract, currency swap
agreement or other similar agreement designed to protect against or manage
exposure to fluctuations in currency values.
"Default" means any event which is, or after notice or passage of time or
both would be, an Event of Default.
"Disqualified Stock" means, with respect to any Person, any Capital Stock
which by its terms (or by the terms of any security into which it is convertible
or for which it is exchangeable at the option of the holder) or upon the
happening of any event:
(1) matures or is mandatorily redeemable (other than redeemable only for
Capital Stock of such Person which is not itself Disqualified Stock) pursuant to
a sinking fund obligation or otherwise;
(2) is convertible or exchangeable at the option of the holder for
Indebtedness or Disqualified Stock; or
(3) is mandatorily redeemable or must be purchased upon the occurrence of
certain events or otherwise, in whole or in part;
on or prior to the first anniversary of the Stated Maturity of the Exchange
Notes; provided, however, that any Capital Stock that would not constitute
Disqualified Stock but for provisions thereof giving holders thereof the right
to require such Person to purchase or redeem such Capital Stock upon the
occurrence of an "asset sale" or "change of control" occurring prior to the
first anniversary of the Stated Maturity of the Exchange Notes shall not
constitute Disqualified Stock if:
(1) the "asset sale" or "change of control" provisions applicable to such
Capital Stock are not more favorable to the holders of such Capital Stock than
the terms applicable to the Exchange Notes and described under "--Certain
Covenants--Limitation on Sales of Assets and Subsidiary Stock" and "-- Change of
Control;" and
(2) any such requirement only becomes operative after compliance with such
terms applicable to the Exchange Notes, including the purchase of any Exchange
Notes tendered pursuant thereto.
The amount of any Disqualified Stock that does not have a fixed redemption,
repayment or repurchase price will be calculated in accordance with the terms of
such Disqualified Stock as if such Disqualified Stock were redeemed, repaid or
repurchased on any date on which the amount of such Disqualified Stock is to be
determined pursuant to the Indenture; provided, however, that if such
Disqualified Stock could not be required to be redeemed, repaid or repurchased
at the time of such determination, the redemption, repayment or repurchase price
will be the book value of such Disqualified Stock as reflected in the most
recent financial statements of such Person.
"EBITDA" for any period means the sum of Consolidated Net Income, plus the
following to the extent deducted in calculating such Consolidated Net Income:
(1) all income tax expense of the Company and its consolidated Restricted
Subsidiaries;
(2) Consolidated Interest Expense;
(3) depreciation and amortization expense of the Company and its
consolidated Restricted Subsidiaries (excluding amortization expense
attributable to a prepaid operating activity item that was paid in cash in a
prior period but including amortization of prepaid turnaround costs); and
(4) all other non-cash charges of the Company and its consolidated
Restricted Subsidiaries (excluding any such non-cash charge to the extent that
it represents an accrual of or reserve for cash expenditures in any future
period);
94
in each case for such period. Notwithstanding the foregoing, the provision for
taxes based on the income or profits of, and the depreciation and amortization
and non-cash charges of, a Restricted Subsidiary shall be added to Consolidated
Net Income to compute EBITDA only to the extent (and in the same proportion,
including by reason of minority interests) that the net income or loss of such
Restricted Subsidiary was included in calculating Consolidated Net Income and
only if a corresponding amount would be permitted at the date of determination
to be dividended to the Company by such Restricted Subsidiary without prior
approval (that has not been obtained), pursuant to the terms of its charter and
all agreements, instruments, judgments, decrees, orders, statutes, rules and
governmental regulations applicable to such Restricted Subsidiary or its
stockholders.
"Equity Offering" means (i) any primary public offering or private
placement to any Person of Capital Stock (other than Disqualified Stock) of the
Company or (ii) any cash capital contribution received by the Company from any
holder of Capital Stock of the Company and which is accounted for as additional
Capital Stock equity (other than Disqualified Stock).
"Exchange Act" means the U.S. Securities Exchange Act of 1934, as amended.
"Free Cash Flow" for any period means EBITDA less the following:
(1) all cash payments with respect to income taxes of the Company and its
Restricted Subsidiaries;
(2) all cash payments with respect to Consolidated Interest Expense; and
(3) all cash capital expenditures of the Company and its Restricted
Subsidiaries;
in each case for such period.
"GAAP" means generally accepted accounting principles in the United States
of America as in effect as of the Issue Date, including those set forth in:
(1) the opinions and pronouncements of the Accounting Principles Board of
the American Institute of Certified Public Accountants;
(2) statements and pronouncements of the Financial Accounting Standards
Board; and
(3) such other statements by such other entity as approved by a significant
segment of the accounting profession.
"Guarantee" means any obligation, contingent or otherwise, of any Person
directly or indirectly guaranteeing any Indebtedness of any Person and any
obligation, direct or indirect, contingent or otherwise, of such Person:
(1) to purchase or pay (or advance or supply funds for the purchase or
payment of) such Indebtedness of such Person (whether arising by virtue of
partnership arrangements, or by agreements to keep-well, to purchase assets,
goods, securities or services, to take-or-pay or to maintain financial statement
conditions or otherwise); or
(2) entered into for the purpose of assuring in any other manner the
obligee of such Indebtedness of the payment thereof or to protect such obligee
against loss in respect thereof (in whole or in part);
provided, however, that the term "Guarantee" shall not include endorsements for
collection or deposit in the ordinary course of business or any subordination of
claims. The term "Guarantee" used as a verb has a corresponding meaning. The
term "Guarantor" shall mean any Person Guaranteeing any obligation.
"Hedging Obligations" of any Person means the obligations of such Person
pursuant to any Interest Rate Agreement, Currency Agreement, Hydrocarbon
Agreement or Commodity Agreement.
"Holder" or "Noteholder" means the Person in whose name a Note is
registered on the Registrar's books.
"Hydrocarbon Agreement" means any purchase or hedging agreement of
hydrocarbons or refined products therefrom, future contract or option, or any
other agreement designed to protect against or manage exposure to fluctuations
in the price of hydrocarbons or refined products therefrom.
"Incur" means issue, assume, Guarantee, incur or otherwise become liable
for; provided, however, that any Indebtedness or Capital Stock of a Person
existing at the time such Person becomes a Restricted Subsidiary (whether by
merger, consolidation,
95
acquisition or otherwise) shall be deemed to be Incurred by such Person at the
time it becomes a Restricted Subsidiary. The term "Incurrence" when used as a
noun has a corresponding meaning. Solely for purposes of determining compliance
with "-- Certain Covenants -- Limitation on Indebtedness:"
(1) amortization of debt discount or the accretion of principal with
respect to a non-interest bearing or other discount security;
(2) the payment of regularly scheduled interest in the form of additional
Indebtedness of the same instrument or the payment of regularly scheduled
dividends on Capital Stock in the form of additional Capital Stock of the same
class and with the same terms; and
(3) the obligation to pay a premium in respect of Indebtedness arising in
connection with the issuance of a notice of redemption or making of a mandatory
offer to purchase such Indebtedness
will not be deemed to be the Incurrence of Indebtedness.
"Indebtedness" means, with respect to any Person on any date of
determination (without duplication):
(1) the principal in respect of (A) indebtedness of such Person for money
borrowed and (B) indebtedness evidenced by notes, debentures, bonds or other
similar instruments for the payment of which such Person is responsible or
liable, including, in each case, any premium on such indebtedness to the extent
such premium has become due and payable;
(2) all Capital Lease Obligations of such Person and all Attributable Debt
in respect of Sale/ Leaseback Transactions entered into by such Person;
(3) all obligations of such Person issued or assumed as the deferred
purchase price of property, all conditional sale obligations of such Person and
all obligations of such Person under any title retention agreement (but
excluding trade accounts payable arising in the ordinary course of business);
(4) all obligations of such Person for the reimbursement of any obligor on
any letter of credit, bankers' acceptance or similar credit transaction (other
than obligations with respect to letters of credit securing obligations (other
than obligations covered in clauses (1) through (3) above) entered into in the
ordinary course of business of such Person to the extent such letters of credit
are not drawn upon or, if and to the extent drawn upon, such drawing is
reimbursed no later than the tenth Business Day following payment on the letter
of credit);
(5) the amount of all obligations of such Person that arise prior to the
first anniversary of the Stated Maturity of the Exchange Notes with respect to
the redemption, repayment or other repurchase of any Capital Stock of such
Person or any Subsidiary of such Person or that are determined by the value of
such Capital Stock, the amount of such obligations to be determined in
accordance with the Indenture (but excluding, in each case, any accrued
dividends);
(6) all obligations of the type referred to in clauses (1) through (5) of
other Persons and all dividends of other Persons for the payment of which, in
either case, such Person is responsible or liable, directly or indirectly, as
obligor, guarantor or otherwise, including by means of any Guarantee;
(7) all obligations of the type referred to in clauses (1) through (6) of
other Persons secured by any Lien on any property or asset 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 assets
and the amount of the obligation so secured; and
(8) to the extent not otherwise included in this definition, Hedging
Obligations of such Person.
Notwithstanding the foregoing, in connection with the purchase by the Company or
any Restricted Subsidiary of any business, the term "Indebtedness" will exclude
post-closing payment adjustments to which the seller may become entitled to the
extent such payment is determined by a final closing balance sheet or such
payment depends on the performance of such business after the closing; provided,
however, that, at the time of closing, the amount of any such payment is not
determinable and, to the extent such payment thereafter becomes fixed and
determined, the amount is paid within 30 days thereafter.
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, upon the occurrence of the contingency giving
rise to the obligation, of any contingent obligations at such date (but
excluding penalties, indemnities and costs); provided, however, that in the case
of Indebtedness sold at a discount, the amount of such Indebtedness at any time
will be the accreted value thereof at such time.
96
"Independent Qualified Party" means an investment banking firm, accounting
firm or appraisal firm of national standing in the United States of the
Company's choice; provided, however, that in each case such firm is not an
Affiliate of the Company.
"Intercompany Trade Arrangements" means transactions between the Company
and the Permitted Holder pursuant to which the Permitted Holder sells
hydrocarbons to the Company in the ordinary course of business and the Company
thereafter transfers the related trade payable to one or more of its
shareholders pending payment thereof and subsequently dividends or otherwise
transfers funds to such shareholder in an amount equal to such trade payable,
which amount is used by such shareholder to discharge such trade payable.
"Interest Rate Agreement" means any interest rate swap agreement, interest
rate cap agreement or other financial agreement or arrangement (including caps,
swaps, floors, collars and similar arrangements) designed to protect against or
manage exposure to fluctuations in interest rates.
"Investment" in any Person means any direct or indirect advance, loan
(other than advances to customers in the ordinary course of business that are
recorded as accounts receivable on the balance sheet of the lender) or other
extensions of credit (including by way of Guarantee or similar arrangement) or
capital contribution to (by means of any transfer of cash or other property to
others or any payment for property or services for the account or use of
others), or any purchase or acquisition of Capital Stock, Indebtedness or other
similar instruments issued by such Person. Except as otherwise provided for
herein, the amount of an Investment shall be its fair value at the time the
Investment is made and without giving effect to subsequent changes in value.
For purposes of the definition of "Unrestricted Subsidiary," the definition
of "Restricted Payment" and the covenant described under "-- Certain Covenants
- -- Limitation on Restricted Payments":
(1) "Investment" shall include the portion (proportionate to the Company's
equity interest in such Subsidiary) of the fair market value of the net assets
of any Subsidiary of the Company at the time that such Subsidiary is designated
an Unrestricted Subsidiary; provided, however, that upon a redesignation of such
Subsidiary as a Restricted Subsidiary, the Company shall be deemed to continue
to have a permanent "Investment" in an Unrestricted Subsidiary in an amount (if
positive) equal to (A) the Company's "Investment" in such Subsidiary at the time
of such redesignation less (B) the portion (proportionate to the Company's
equity interest in such Subsidiary) of the fair market value of the net assets
of such Subsidiary at the time of such redesignation; and
(2) any property transferred to or from an Unrestricted Subsidiary shall be
valued at its fair market value at the time of such transfer, in each case as
determined in good faith by the Board of Directors of the Company.
"Investment Grade Rating" means:
(1) a Moody's rating of Baa3 or higher and an S&P rating of at least BB+ or
(2) a Moody's rating of Ba1 or higher and an S&P rating of at least BBB-;
provided, however, that if (i) either Moody's or S&P changes its rating system,
such ratings will be the equivalent ratings after such changes or (ii) if S&P or
Moody's or both shall not make a rating of the Exchange Notes publicly
available, the references above to S&P or Moody's or both, as the case may be,
shall be to a nationally recognized U.S. rating agency or agencies, as the case
may be, selected by the Company and the references to the ratings categories
above shall be to the corresponding rating categories of such rating agency or
rating agencies, as the case may be.
"Investment Grade Rating Event" means the first day on which the Exchange
Notes are assigned an Investment Grade Rating.
"Issue Date" means February 27, 2003.
"LCR" means Lyondell-CITGO Refining LP, a Delaware limited partnership.
"Legal Holiday" means a Saturday, a Sunday or a day on which banking
institutions are not required to be open in the State of New York.
"Lenders" has the meaning specified in each Credit Agreement.
"Lien" means any mortgage, pledge, security interest, encumbrance, lien or
charge of any kind (including any conditional sale or other title retention
agreement or lease in the nature thereof).
97
"Material Investment" means an Investment which has, at the time such
Investment is made and without giving effect to subsequent changes in value, a
fair value in excess of $5 million.
"Moody's" means Moody's Investors Service, Inc. and its successors.
"Net Available Cash" from an Asset Disposition means cash payments received
therefrom (including any cash payments received by way of deferred payment of
principal pursuant to a note or installment receivable or otherwise and proceeds
from the sale or other disposition of any securities received as consideration,
but only as and when received, but excluding any other consideration received in
the form of assumption by the acquiring Person of Indebtedness or other
obligations relating to such properties or assets or received in any other
non-cash form), in each case net of:
(1) all legal, title and recording tax expenses, commissions and other fees
and expenses incurred, and all Federal, state, provincial, foreign and local
taxes required to be accrued as a liability under GAAP, as a consequence of such
Asset Disposition;
(2) all payments made on any Indebtedness which is secured by any assets
subject to such Asset Disposition, in accordance with the terms of any Lien upon
or other security agreement of any kind with respect to such assets, or which
must by its terms, or in order to obtain a necessary consent to such Asset
Disposition, or by applicable law, be repaid out of the proceeds from such Asset
Disposition;
(3) all distributions and other payments required to be made to minority
interest holders in Restricted Subsidiaries as a result of such Asset
Disposition; and
(4) the deduction of appropriate amounts provided by the seller as a
reserve, in accordance with GAAP, against any liabilities associated with the
property or other assets disposed in such Asset Disposition and retained by the
Company or any Restricted Subsidiary after such Asset Disposition.
"Net Cash Proceeds" with respect to any issuance or sale of Capital Stock
or Indebtedness, means the cash proceeds of such issuance or sale 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.
"New Credit Agreement" means the credit agreement that the Company entered
into on February 27, 2003 and which is described under "Management's Discussion
and Analysis of Financial Condition and Results of Operations -- Liquidity and
Capital Resources," together with the related documents thereto (including the
term loan or revolving loan facility, note purchase or placement facility,
letter of credit facility or other arrangement for the extension of credit
thereunder, any guarantees and security documents), as amended, extended,
renewed, restated, supplemented or otherwise modified (in whole or in part, and
without limitation as to amount, terms, conditions, covenants and other
provisions) from time to time, and any agreement (and related document)
governing Indebtedness Incurred to Refinance, in whole or in part, the
borrowings and commitments then outstanding or permitted to be outstanding under
such credit agreement or a successor credit agreement, whether by the same or
any other lender or group of lenders.
"Obligations" means, with respect to any Indebtedness, all obligations for
principal, premium, interest, penalties, fees, indemnifications, reimbursements,
and other amounts payable pursuant to the documentation governing such
Indebtedness.
"Officer" means the Chairman of the Board, the President, any Vice
President, the Treasurer or the Secretary of the Company.
"Officers' Certificate" means a certificate signed by two Officers.
"Opinion of Counsel" means a written opinion from legal counsel who is
acceptable to the Trustee. The counsel may be an employee of or counsel to the
Company or the Trustee.
"Ordinary Course Guarantees" means Guarantees issued by the Company or any
Restricted Subsidiary in the ordinary course of business with respect to
Indebtedness of any distributor or customer of the Company's or any Restricted
Subsidiary's products in an amount which, when taken together with the amount of
all other outstanding Ordinary Course Guarantees, does not exceed $35 million.
"Outstanding Notes" means the notes 113/8% Senior Notes due 2011 of the
Company issued on February 27, 2003.
"Permitted Holder" means Petroleos de Venezuela, SA, a corporation
organized in Venezuela and its wholly owned Subsidiaries.
98
"PDV America" means PDV America, Inc., a Delaware corporation.
"Permitted Investment" means an Investment by the Company or any Restricted
Subsidiary in:
(1) the Company, a Restricted Subsidiary, a government or any agency or
political subdivision thereof holding Indebtedness of the Company or a
Restricted Subsidiary in a principal amount equal to, and Incurred by the
Company or such Restricted Subsidiary to provide credit support for, such
Person's issuance of industrial revenue or similar tax-exempt bonds for the
benefit of the Company or such Restricted Subsidiary or a Person that will, upon
the making of such Investment, become a Restricted Subsidiary; provided,
however, that the primary business of such Restricted Subsidiary is a Related
Business;
(2) another Person if, as a result of such Investment, such other Person is
merged or consolidated with or into, or transfers or conveys all or
substantially all its assets to, the Company or a Restricted Subsidiary;
provided, however, that such Person's primary business is a Related Business;
(3) cash and Temporary Cash Investments;
(4) receivables owing to the Company or any Restricted Subsidiary if
created or acquired in the ordinary course of business and payable or
dischargeable in accordance with customary trade terms; provided, however, that
such trade terms may include such concessionary trade terms as the Company or
any such Restricted Subsidiary deems reasonable under the circumstances;
(5) payroll, travel, entertainment, relocation and similar advances to
cover matters that are expected at the time of such advances ultimately to be
treated as expenses for accounting purposes and that are made in the ordinary
course of business;
(6) loans or advances to employees made in the ordinary course of business
consistent with past practices of the Company or such Restricted Subsidiary;
(7) stock, obligations or securities received in settlement of debts
created in the ordinary course of business and owing to the Company or any
Restricted Subsidiary or in satisfaction of judgments;
(8) any Person to the extent such Investment represents the non-cash
portion of the consideration received for an Asset Disposition as permitted
pursuant to the covenant described under "-- Certain Covenants -- Limitation on
Sales of Assets and Subsidiary Stock;"
(9) any Person where such Investment was acquired by the Company or any of
its Restricted Subsidiaries (a) in exchange for any other Investment or accounts
receivable held by the Company or any such Restricted Subsidiary in connection
with or as a result of a bankruptcy, workout, reorganization or recapitalization
of the issuer of such other Investment or accounts receivable or (b) as a result
of a foreclosure by the Company or any of its Restricted Subsidiaries with
respect to any secured Investment or other transfer of title with respect to any
secured Investment in default;
(10) any Person to the extent such Investments consist of prepaid expenses,
negotiable instruments held for collection and lease, utility and workers'
compensation, performance and other similar deposits made in the ordinary course
of business by the Company or any Restricted Subsidiary;
(11) any Person to the extent such Investments consist of Hedging
Obligations otherwise not prohibited under the covenant described under "--
Certain Covenants -- Limitation on Indebtedness;"
(12) any Person to the extent such Investments are in existence on the
Issue Date;
(13) LCR to the extent such Investments do not exceed, in the aggregate,
the aggregate amount of cash dividends distributed after the Issue Date by LCR
to the Company; provided, however, that such cash dividends have not previously
served as the basis for a Restricted Payment made pursuant to the covenant
described under "-- Certain Covenants -- Limitation on Restricted Payments;"
(14) LCR to the extent such Investments do not exceed $25 million in the
aggregate outstanding at any time; and
(15) Persons to the extent such Investments, when taken together with all
other Investments made pursuant to this clause (15) and then outstanding, do not
exceed $75 million.
99
"Permitted Liens" means, with respect to any Person:
(1) pledges or deposits by such Person under worker's compensation laws,
unemployment insurance laws or similar legislation, or good faith deposits in
connection with bids, tenders, contracts (other than for the payment of
Indebtedness) or leases to which such Person is a party, or deposits to secure
public or statutory obligations of such Person or deposits of cash or United
States government bonds to secure surety or appeal bonds to which such Person is
a party, or deposits as security for contested taxes or import duties or for the
payment of rent, in each case Incurred in the ordinary course of business;
(2) Liens imposed by law, such as carriers', warehousemen's, materialmen's
and mechanics' Liens, in each case for sums which are not overdue by a period of
more than 45 days or which are being contested in good faith by appropriate
proceedings or other Liens arising out of judgments or awards against such
Person with respect to which such Person shall then be proceeding with an appeal
or other proceedings for review and Liens arising solely by virtue of any
statutory or common law provision relating to banker's Liens, rights of set-off
or similar rights and remedies as to deposit accounts or other funds maintained
with a creditor depository institution; provided, however, that (A) such deposit
account is not a dedicated cash collateral account and is not subject to
restrictions against access by the Company in excess of those set forth by
regulations promulgated by the Federal Reserve Board and (B) such deposit
account is not intended by the Company or any Restricted Subsidiary to provide
collateral to the depository institution;
(3) Liens for property taxes not yet subject to penalties for non-payment
or which are being contested in good faith by appropriate proceedings;
(4) Liens in favor of issuers of surety bonds or letters of credit issued
pursuant to the request of and for the account of such Person in the ordinary
course of its business; provided, however, that such letters of credit do not
constitute Indebtedness;
(5) Liens incidental to the normal conduct of the business of such Person
or any of its Subsidiaries or the ownership of its properties or the conduct of
the ordinary course of its business, including (A) zoning restrictions,
easements, rights of way, reservations, restrictions on the use of real property
and other minor irregularities of title, (B) rights of lessees under leases, (C)
rights of collecting banks having rights of setoff, revocation, refund or
chargeback with respect to money or instruments of such Person or any of its
Subsidiaries on deposit with or in the possession of such banks, (D) Liens to
secure the performance of statutory obligations, tenders, bids, leases, progress
payments, performance or return-of-money bonds, performance or other similar
bonds or other obligations of a similar nature incurred in the ordinary course
of business; (E) Liens required by any contract or statute in order to permit
such Person or any of its Subsidiaries to perform any contract or subcontract
made by it with or pursuant to the requirements of a governmental entity, and
(F) "first purchaser" Liens on crude oil, in each case which are not incurred in
connection with the Incurrence of Indebtedness and which do not in the aggregate
impair the use and operation of the assets to which they relate in the conduct
of the business of such Person and its Subsidiaries taken as a whole;
(6) Liens securing Indebtedness Incurred to finance the construction,
purchase or lease of, or repairs, improvements or additions to, property, plant
or equipment of such Person; provided, however, that the Lien may not extend to
any other property owned by such Person or any of its Restricted Subsidiaries at
the time the Lien is Incurred (other than assets and property affixed or
appurtenant thereto), and the Indebtedness (other than any interest thereon)
secured by the Lien may not be Incurred more than 180 days after the later of
the acquisition, completion of construction, repair, improvement, addition or
commencement of full operation of the property subject to the Lien;
(7) Liens to secure Indebtedness Incurred pursuant to clause (b)(1) or
(b)(3) under "-- Certain Covenants -- Limitation on Indebtedness;"
(8) Liens on the Capital Stock of the Pledged Entities to secure
Indebtedness Incurred pursuant to clause (b)(2) under "-- Certain Covenants --
Limitation on Indebtedness;"
(9) Liens existing on the Issue Date;
(10) Liens on property or shares of Capital Stock of another Person at the
time such other Person becomes a Subsidiary of such Person; provided, however,
that the Liens may not extend to any other property owned by such Person or any
of its Restricted Subsidiaries (other than assets and property affixed or
appurtenant thereto);
(11) Liens on property at the time such Person or any of its Subsidiaries
acquires the property, including any acquisition by means of a merger or
consolidation with or into such Person or a Subsidiary of such Person; provided,
however, that the Liens may not extend to any other property owned by such
Person or any of its Restricted Subsidiaries (other than assets and property
affixed or appurtenant thereto);
(12) Liens securing Indebtedness or other obligations of a Subsidiary of
such Person owing to such Person or a Restricted Subsidiary;
100
(13) Liens securing Hedging Obligations permitted to be Incurred under the
Indenture;
(14) customary Liens incurred by the Company or any Restricted Subsidiary
and resulting from a Qualified Receivables Transaction;
(15) Liens on properties securing all or part of the costs incurred in the
ordinary course of business of exploration, drilling, development or operation
thereof;
(16) Liens on pipeline or pipeline facilities which arise out of operation
of law;
(17) Liens reserved in oil and gas mineral leases for bonus or rental
payments and for compliance with the terms of such leases;
(18) Liens arising under partnership agreements, oil and gas leases,
farm-out agreements, division orders, contracts for the sale, purchase,
exchange, transportation or processing of oil, gas or other hydrocarbons,
unitization and pooling declarations and agreements, development agreements,
operating agreements, area of mutual interest agreements, and other agreements
which are customary in a Related Business; and
(19) Liens to secure any Refinancing (or successive Refinancings) as a
whole, or in part, of any Indebtedness secured by any Lien referred to in the
foregoing clause (6), (9) or (11); provided, however, that:
(A) such new Lien shall be limited to all or part of the same property and
assets that secured or, under the written agreements pursuant to which the
original Lien arose, could secure the original Lien (plus improvements and
accessions to, such property or proceeds or distributions thereof); and
(B) the Indebtedness secured by such Lien at such time is not increased to
any amount greater than the sum of (x) the outstanding principal amount or, if
greater, committed amount of the Indebtedness described under clause (6), (9) or
(11), at the time the original Lien became a Permitted Lien and (y) an amount
necessary to pay any fees and expenses, including premiums, related to such
refinancing, refunding, extension, renewal or replacement.
Notwithstanding the foregoing, "Permitted Liens" will not include any Lien
described in clause (6), (9) or (11) above to the extent such Lien applies to
any Additional Assets acquired directly or indirectly from Net Available Cash
pursuant to the covenant described under "-- Certain Covenants -- Limitation on
Sales of Assets and Subsidiary Stock." For purposes of this definition, the term
"Indebtedness" shall be deemed to include interest on such Indebtedness.
"Person" means any individual, corporation, partnership, limited liability
company, joint venture, association, joint-stock company, trust, unincorporated
organization, government or any agency or political subdivision thereof or any
other entity.
"Pledged Entities" means CITGO Pipeline I and CITGO Pipeline II.
"Preferred Stock," as applied to the Capital Stock of any Person, means
Capital Stock of any class or classes (however designated) which is preferred as
to the payment of dividends or distributions, or as to the distribution of
assets upon any voluntary or involuntary liquidation or dissolution of such
Person, over shares of Capital Stock of any other class of such Person.
"principal" of an Exchange Note means the principal of the Exchange Note
plus the premium, if any, payable on the Exchange Note which is due or overdue
or is to become due at the relevant time.
"Principal Property" means:
(1) any refinery and related pipelines, terminalling and processing
equipment or
(2) any other real property or marketing assets or related group of our
assets having a fair market value in excess of $20 million.
"Qualified Receivables Transaction" means any transaction or series of
transactions entered into by the Company or any of its Restricted Subsidiaries
pursuant to which the Company or any of its Restricted Subsidiaries sells,
conveys or otherwise transfers to (i) a Receivables Subsidiary (in the case of a
transfer by the Company or any of its Restricted Subsidiaries) and (ii) any
other Person (in the case of a transfer by a Receivables Subsidiary), or grants
a security interest in, any accounts receivable (whether now existing or arising
in the future) of the Company or any of its Restricted Subsidiaries, and any
assets related thereto, including all collateral securing such accounts
receivable, all contracts and all guarantees or other obligations in respect of
such accounts receivable, proceeds of such accounts receivable and other assets
which are customarily transferred or in respect of which security interests are
customarily
101
granted in connection with asset securitization transactions involving accounts
receivable; provided, however, that the accounts receivable of the Company or
any of its Restricted Subsidiaries subject to all Qualified Receivables
Transactions and outstanding on the date any such accounts receivable are
transferred by the Company or a Restricted Subsidiary have, together with the
accounts receivable transferred on such date, a balance that does not exceed in
the aggregate the greater of (A) $400,000,000 and (B) 5% of net sales of the
Company and its Restricted Subsidiaries during the four fiscal quarter period
ending on the last day of the most recent fiscal quarter for which the Company
has issued consolidated financial statements.
"Receivables Subsidiary" means a Subsidiary of the Company which engages in
no activities other than in connection with the financing of accounts receivable
and which is designated by the Board of Directors of the Company (as provided
below) as a Receivables Subsidiary (a) no portion of the Indebtedness or any
other Obligations (contingent or otherwise) of which (i) is Guaranteed by the
Company or any of its Restricted Subsidiaries (but excluding customary
representations, warranties, covenants and indemnities entered into in the
ordinary course of business in connection with a Qualified Receivables
Transaction), (ii) is recourse to or obligates the Company or any of its
Restricted Subsidiaries in any way other than pursuant to customary
representations, warranties, covenants and indemnities entered into in
connection with a Qualified Receivables Transaction or (iii) subjects any
property or asset of the Company or any of its Restricted Subsidiaries (other
than accounts receivable and interests therein and related assets as provided in
the definition of "Qualified Receivables Transaction"), directly or indirectly,
contingently or otherwise, to the satisfaction thereof, other than pursuant to
customary representations, warranties, covenants and indemnities entered into in
the ordinary course of business in connection with a Qualified Receivables
Transaction, (b) with which neither the Company nor any of its Restricted
Subsidiaries has any material contract, agreement, arrangement or understanding
other than on terms no less favorable to the Company or such Restricted
Subsidiary than those that might be obtained at the time from Persons who are
not Affiliates of the Company, other than fees payable in the ordinary course of
business in connection with servicing accounts receivable and (c) with which
neither the Company nor any of its Restricted Subsidiaries has any obligation to
maintain or preserve such Subsidiary's financial condition or cause such
Subsidiary to achieve certain levels of operating results. Any such designation
by the Board of Directors of the Company will be evidenced to the Trustee by
filing with the Trustee a certified copy of the resolution of the Board of
Directors of the Company giving effect to such designation and an Officer's
Certificate certifying that such designation complied with the foregoing
conditions.
"Reference Period" means, with respect to any Restricted Payment, the
period consisting of the most recent consecutive fiscal quarters (not to exceed
4) of the Company commencing no earlier than January 1, 2003, and ending at
least 45 days prior to the date such Restricted Payment is made.
"Refinance" means, in respect of any Indebtedness, to refinance, extend,
renew, refund, repay, prepay, redeem, defease or retire, or to issue other
Indebtedness in exchange or replacement for, such Indebtedness. "Refinanced" and
"Refinancing" shall have correlative meanings.
"Refinancing Indebtedness" means Indebtedness that Refinances any
Indebtedness of the Company or any Restricted Subsidiary existing on the Issue
Date or Incurred in compliance with the Indenture, including Indebtedness that
Refinances Refinancing Indebtedness; provided, however, that:
(1) such Refinancing Indebtedness has a Stated Maturity no earlier than the
Stated Maturity of the Indebtedness being Refinanced;
(2) such Refinancing Indebtedness has an Average Life at the time such
Refinancing Indebtedness is Incurred that is equal to or greater than the
Average Life of the Indebtedness being Refinanced;
(3) such Refinancing Indebtedness has an aggregate principal amount (or if
Incurred with original issue discount, an aggregate issue price) that is equal
to or less than the aggregate principal amount (or if Incurred with original
issue discount, the aggregate accreted value) then outstanding or committed
(plus fees and expenses, including any premium and defeasance costs) under the
Indebtedness being Refinanced; and
(4) if the Indebtedness being Refinanced is subordinated in right of
payment to the Exchange Notes, such Refinancing Indebtedness is subordinated in
right of payment to the Exchange Notes at least to the same extent as the
Indebtedness being Refinanced;
provided further, however, that Refinancing Indebtedness shall not include (A)
Indebtedness of a Subsidiary that Refinances Indebtedness of the Company or (B)
Indebtedness of the Company or a Restricted Subsidiary that Refinances
Indebtedness of an Unrestricted Subsidiary.
"Related Business" means any business in which the Company was engaged on
the Issue Date and any business related, ancillary or complementary to any
business of the Company in which the Company was engaged on the Issue Date.
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"Restricted Payment" with respect to any Person means:
(1) the declaration or payment of any dividends or any other distributions
of any sort in respect of its Capital Stock (including any payment in connection
with any merger or consolidation involving such Person) or similar payment to
the direct or indirect holders of its Capital Stock (other than dividends or
distributions payable solely in its Capital Stock (other than Disqualified
Stock) and dividends or distributions payable solely to the Company or a
Restricted Subsidiary, and other than pro rata dividends or other distributions
made by a Subsidiary that is not a Wholly Owned Subsidiary to minority
stockholders (or owners of an equivalent interest in the case of a Subsidiary
that is an entity other than a corporation));
(2) the purchase, redemption or other acquisition or retirement for value
of any Capital Stock of the Company held by any Person or of any Capital Stock
of a Restricted Subsidiary held by any Affiliate of the Company (other than a
Restricted Subsidiary), including in connection with any merger or consolidation
and including the exercise of any option to exchange any Capital Stock (other
than into Capital Stock of the Company that is not Disqualified Stock);
(3) the purchase, repurchase, redemption, defeasance or other acquisition
or retirement for value, prior to scheduled maturity, scheduled repayment or
scheduled sinking fund payment of any Subordinated Obligations of such Person
(other than the purchase, repurchase or other acquisition of Subordinated
Obligations purchased in anticipation of satisfying a sinking fund obligation,
principal installment or final maturity, in each case due within one year of the
date of such purchase, repurchase or other acquisition); or
(4) the making of any Investment (other than a Permitted Investment) in any
Person.
Notwithstanding the foregoing, Intercompany Trade Arrangements shall not be
included in the definition of "Restricted Payment."
"Restricted Subsidiary" means any Subsidiary of the Company that is not an
Unrestricted Subsidiary.
"Sale/Leaseback Transaction" means an arrangement relating to property
owned by the Company or a Restricted Subsidiary on the Issue Date or thereafter
acquired by the Company or a Restricted Subsidiary whereby the Company or a
Restricted Subsidiary transfers such property to a Person and the Company or a
Restricted Subsidiary leases it from such Person.
"S&P" means Standard & Poor's Ratings Group, a division of The McGraw-Hill
Companies, Inc., and its successors.
"SEC" means the U.S. Securities and Exchange Commission.
"Securities Act" means the U.S. Securities Act of 1933, as amended.
"Senior Indebtedness" means with respect to any Person:
(1) Indebtedness of such Person, whether outstanding on the Issue Date or
thereafter Incurred; and
(2) all other Obligations of such Person (including interest accruing on or
after the filing of any petition in bankruptcy or for reorganization relating to
such Person whether or not post-filing interest is allowed in such proceeding)
in respect of Indebtedness described in clause (1) above,
unless, in the case of clauses (1) and (2), in the instrument creating or
evidencing the same or pursuant to which the same is outstanding, it is provided
that such Indebtedness or other obligations are subordinate in right of payment
to the Exchange Notes; provided, however, that Senior Indebtedness shall not
include:
(1) any obligation of such Person to the Company or any Subsidiary of the
Company;
(2) any liability for Federal, state, local or other taxes owed or owing by
such Person;
(3) any accounts payable or other liability to trade creditors arising in
the ordinary course of business (including guarantees thereof or instruments
evidencing such liabilities);
(4) any Indebtedness or other Obligation of such Person which is
subordinate or junior in any respect to any other Indebtedness or other
Obligation of such Person; or
(5) that portion of any Indebtedness which at the time of Incurrence is
Incurred in violation of the Indenture.
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"Significant Subsidiary" means any Restricted Subsidiary that would be a
"Significant Subsidiary" of the Company within the meaning of Rule 1-02 under
Regulation S-X promulgated by the SEC.
"Stated Maturity" means, with respect to any security, the date specified
in such security as the fixed date on which the final payment of principal of
such security 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 Obligation" means, with respect to any Person, any
Indebtedness of such Person (whether outstanding on the Issue Date or thereafter
Incurred) which is subordinate or junior in right of payment to the Exchange
Notes or a Subsidiary Guaranty of such person, as the case may be, pursuant to a
written agreement to that effect.
"Subsidiary" means, with respect to any Person, any corporation,
association, partnership or other business entity of which more than 50% of the
total voting power of shares of Voting Stock is at the time owned or controlled,
directly or indirectly, by:
(1) such Person;
(2) such Person and one or more Subsidiaries of such Person; or
(3) one or more Subsidiaries of such Person.
"Subsidiary Guarantor" means any Restricted Subsidiary of the Company if
and so long as such Restricted Subsidiary guarantees payment of the Exchange
Notes on the terms and conditions set forth in the Indenture. As of the Issue
Date there will be no Subsidiary Guarantors.
"Subsidiary Guaranty" means a Guarantee by a Subsidiary Guarantor of the
Company's obligations with respect to the Exchange Notes.
"Temporary Cash Investments" means any of the following:
(1) any investment in direct obligations of the United States of America or
any agency thereof or obligations guaranteed by the United States of America or
any agency thereof;
(2) investments in demand and time deposit accounts, certificates of
deposit, eurodollar time deposits and money market deposits maturing within 360
days of the date of acquisition thereof issued by a bank or trust company which
is organized under the laws of the United States of America, any State thereof
or any foreign country recognized by the United States of America, and which
bank or trust company has capital, surplus and undivided profits aggregating in
excess of $50 million (or the foreign currency equivalent thereof) and has
outstanding debt which is rated "A" (or such similar equivalent rating) or
higher by at least one nationally recognized statistical rating organization (as
defined in Rule 436 under the Securities Act) or any money-market fund sponsored
by a registered broker dealer or mutual fund distributor;
(3) repurchase obligations with a term of not more than 30 days for
underlying securities of the types described in clause (1) above entered into
with a bank meeting the qualifications described in clause (2) above;
(4) investments in commercial paper, maturing not more than 360 days after
the date of acquisition, issued by a corporation (other than an Affiliate of the
Company) organized and in existence under the laws of the United States of
America or any foreign country recognized by the United States of America with a
rating at the time as of which any investment therein is made of "P-2" (or
higher) according to Moody's or "A-2" (or higher) according to S&P; and
(5) investments in securities with maturities of six months or less from
the date of acquisition issued or fully guaranteed by any state, commonwealth or
territory of the United States of America, or by any political subdivision or
taxing authority thereof, and rated at least "A" by S&P or "A2" by Moody's;
provided, however, that if S&P or Moody's or both shall not make ratings of
commercial paper of the type referred to in clause (4) above or securities of
the type referred to in clause (5) above publicly available, the references in
clause (4) or (5) or both, as the case may be, to S&P or Moody's or both, as the
case may be, shall be to a nationally recognized U.S. rating agency or agencies,
as the case may be, selected by the Company and the references to the ratings
categories in clause (4) or (5) or both, as the case may be, shall be to the
corresponding rating categories of such rating agency or rating agencies, as the
case may be.
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"364-Day Credit Agreement" means the 364-day credit agreement entered into
as of December 11, 2002, among the Company, the lenders referred to therein and
Bank of America, N.A. as Administrative Agent together with the related
documents thereto (including the revolving loan facility, note purchase or
placement facility, letter of credit facility or other arrangement for the
extension of credit thereunder, any guarantees and security documents), as
amended, extended, renewed, restated, supplemented or otherwise modified (in
whole or in part, and without limitation as to amount, terms, conditions,
covenants and other provisions) from time to time, and any agreement (and
related document) governing Indebtedness incurred to Refinance, in whole or in
part, the borrowings and commitments then outstanding or permitted to be
outstanding under such credit agreement or a successor credit agreement, whether
by the same or any other lender or group of lenders.
"Three-Year Credit Agreement" means the three-year credit agreement entered
into as of December 11, 2002, among the Company, the lenders referred to therein
and Bank of America, N.A. as Administrative Agent, together with the related
documents thereto (including the revolving loan facility, note purchase or
placement facility, letter of credit facility or other arrangement for the
extension of credit thereunder, any guarantees and security documents), as
amended, extended, renewed, restated, supplemented or otherwise modified (in
whole or in part, and without limitation as to amount, terms, conditions,
covenants and other provisions) from time to time, and any agreement (and
related document) governing Indebtedness incurred to Refinance, in whole or in
part, the borrowings and commitments then outstanding or permitted to be
outstanding under such credit agreement or a successor credit agreement, whether
by the same or any other lender or group of lenders.
"Trustee" means The Bank of New York until a successor replaces it and,
thereafter, means the successor.
"Trust Indenture Act" means the Trust Indenture Act of 1939 (15 U.S.C.
Sections 77aaa-77bbbb) as in effect on the Issue Date.
"Trust Officer" means the Chairman of the Board, the President or any other
officer or assistant officer of the Trustee assigned by the Trustee to
administer its corporate trust matters.
"Unrestricted Subsidiary" means:
(1) any Subsidiary of the Company that at the time of determination shall
be designated an Unrestricted Subsidiary by the Board of Directors of the
Company in the manner provided below; and
(2) any Subsidiary of an Unrestricted Subsidiary.
The Board of Directors of the Company may designate any Subsidiary of the
Company (including any newly acquired or newly formed Subsidiary) to be an
Unrestricted Subsidiary unless such Subsidiary or any of its Subsidiaries owns
any Capital Stock or Indebtedness of, or holds any Lien on any property of, the
Company or any other Subsidiary of the Company that is not a Subsidiary of the
Subsidiary to be so designated or an Unrestricted Subsidiary; provided, however,
that either (A) the Subsidiary to be so designated has total assets of $1,000 or
less or (B) if such Subsidiary has assets greater than $1,000, such designation
would be permitted under the covenant described under "-- Certain Covenants --
Limitation on Restricted Payments."
The Board of Directors of the Company may designate any Unrestricted
Subsidiary to be a Restricted Subsidiary; provided, however, that immediately
after giving effect to such designation (A) the Company could Incur $1.00 of
additional Indebtedness under paragraph (a) of the covenant described under "--
Certain Covenants -- Limitation on Indebtedness" and (B) no Default shall have
occurred and be continuing.
Any such designation by the Board of Directors of the Company shall be
evidenced to the Trustee by promptly filing with the Trustee a copy of the
resolution of the Board of Directors of the Company giving effect to such
designation and an Officers' Certificate certifying that such designation
complied with the foregoing provisions.
"U.S. Government Obligations" means direct obligations (or certificates
representing an ownership interest in such obligations) of the United States of
America (including any agency or instrumentality thereof) for the payment of
which the full faith and credit of the United States of America is pledged and
which are not callable at the issuer's option.
"Voting Stock" of a Person means all classes of Capital Stock or other
interests (including partnership interests) of such Person then outstanding and
normally entitled (without regard to the occurrence of any contingency) to vote
in the election of directors, managers or trustees thereof.
"Wholly Owned Subsidiary" means a Restricted Subsidiary all the Capital
Stock of which (other than directors' qualifying shares) is owned by the Company
or one or more Wholly Owned Subsidiaries.
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SUMMARY OF U.S. FEDERAL INCOME TAX CONSIDERATIONS
The following is a summary of the material United States federal income tax
consequences of the acquisition, ownership and disposition of exchange notes by
beneficial owners thereof, or exchange noteholders. It deals only with exchange
notes acquired in the exchange offer upon surrender of outstanding notes
acquired by the exchanging noteholder upon original issuance. Furthermore, it
deals only with noteholders that acquire and hold the exchange notes as capital
assets and does not deal with special situations, such as those of dealers in
securities or currencies, real estate investment trusts, regulated investment
companies, tax exempt entities, financial institutions, insurance companies,
persons holding the notes as a part of a hedging or conversion transaction or a
straddle, or investors whose "functional currency" is not the United States
dollar. This summary is based on the Internal Revenue Code of 1986, as amended
(the "Code"), administrative pronouncements, judicial decisions and Treasury
Regulations, changes to any of which subsequent to the date of this offering
circular may affect the tax consequences described herein, possibly with
retroactive effect. Holders considering exchanging outstanding notes for
exchange notes should consult their own tax advisors concerning the federal
income tax consequences of holding the exchange notes in light of their
particular situations as well as any consequences arising under the laws of any
other taxing jurisdiction. The tax consequences of any Additional Notes may
differ from the tax consequences described herein.
As used herein, the term "U.S. Holder" means a beneficial owner of an
exchange note who or which is, for United States federal income tax purposes, a
citizen or resident of the United States, a corporation created or organized in
or under the laws of the United States or any state thereof (including the
District of Columbia), or an estate or trust treated as a United States person
under section 7701(a)(30) of the Code. The term "Non-U.S. Holder" means any
beneficial owner of an exchange note that is not a U.S. Holder. If a partnership
holds exchange notes, the tax treatment of a partner will generally depend upon
the status of the partner and the activities of the partnership. Partners in a
partnership holding exchange notes should consult their tax advisors.
TREATMENT OF EXCHANGES UNDER EXCHANGE OFFER
The exchange of the outstanding notes for exchange notes will not be a
taxable event for United States federal income tax purposes. An exchange
noteholder will not recognize any taxable gain or loss as a result of exchanging
outstanding notes for exchange notes, and the holder will have the same tax
basis and holding period in the exchange notes as the holder had in the
outstanding notes immediately before exchange.
U.S. HOLDERS
INTEREST
Interest on the exchange notes will be taxed to a U.S. Holder as ordinary
interest income at the time it accrues or is received, in accordance with the
U.S. Holder's regular method of accounting for federal income tax purposes.
AMORTIZABLE BOND PREMIUM
If a U.S. Holder purchases an exchange note in a secondary market
transaction for an amount in excess of, in general, the note's principal amount,
such U.S. Holder will be considered to have purchased such note with
"amortizable bond premium" equal in amount to such excess. Generally, a U.S.
Holder may elect to amortize such premium as an offset to interest income, using
a constant yield method. The premium amortization is calculated assuming that we
will exercise redemption rights in a manner that maximizes the U.S. Holder's
yield. A U.S. Holder that elects to amortize bond premium must reduce its tax
basis in the exchange note by the amount of the premium used to offset interest
income as set forth above. An election to amortize bond premium applies to all
taxable debt obligations held during or after the taxable year for which the
election is made and may be revoked only with the consent of the Internal
Revenue Service (the "IRS").
MARKET DISCOUNT
If a U.S. Holder acquires an exchange note in a secondary market
transaction for an amount that is less than, in general, the exchange note's
principal amount, the amount of such difference is treated as "market discount"
for federal income tax purposes, unless such difference is considered to be de
minimis as described in section 1278(a)(2)(C) of the Code. Under the market
discount rules of the Code, a U.S. Holder is required to treat any principal
payment on, or any gain on the sale, exchange, retirement or other disposition
of, an exchange note as ordinary income to the extent of the accrued market
discount that has not previously been included in income. In general, the amount
of market discount that has accrued is determined on a ratable basis although in
certain circumstances an election may be made to accrue market discount on a
constant interest basis. A U.S. Holder may not be allowed to deduct immediately
a portion of the interest expense on any indebtedness incurred or continued to
purchase or to carry exchange notes with market discount. A U.S. Holder may
elect to include market discount in income currently as it accrues, in which
case the interest deferral rule set forth in the preceding sentence will not
apply. Such an election will apply to all debt instruments acquired by the U.S.
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Holder on or after the first day of the first taxable year to which such
election applies and is irrevocable without the consent of the IRS. A U.S.
Holder's tax basis in an exchange note will be increased by the amount of market
discount included in such U.S. Holder's income under such election. U.S. Holders
of exchange notes with market discount are urged to consult their tax advisors
as to the tax consequences of ownership and disposition of the exchange notes.
DISPOSITION OF NOTES
A U.S. Holder who disposes of an exchange note by sale, exchange for other
property, or payment by us, will recognize taxable gain or loss equal to the
difference between the amount realized on the sale or other disposition (not
including any amount attributable to accrued but unpaid interest) and the U.S.
Holder's adjusted tax basis in the exchange note. Any amount attributable to
accrued but unpaid interest will be treated as a payment of interest and taxed
in the manner described above under "Summary of U.S. Federal Income Tax
Considerations -- U.S. Holders -- Interest." Any amount attributable to accrued
market discount that has not previously been included in income will be taxed in
the manner described above under "Summary of U.S. Federal Income Tax
Considerations -- U.S. Holders -- Market Discount." In general, the U.S.
Holder's adjusted tax basis in an exchange note will be equal to the purchase
price of the exchange note paid by the U.S. Holder (excluding any amount
attributable to accrued but unpaid interest) increased by the amount of market
discount previously included in the U.S. Holder's income with respect to the
exchange note and reduced by any bond premium used to offset interest income as
described above under "Summary of U.S. Federal Income Tax Considerations -- U.S.
Holders -- Amortizable Bond Premium."
Gain or loss realized on the sale, exchange or retirement of an exchange
note generally will be capital gain or loss (subject to the market discount
rules described above under "Summary of U.S. Federal Income Tax Considerations
- -- U.S. Holders -- Market Discount"), and will be long-term capital gain or loss
if at the time of sale, exchange or retirement the exchange note has been held
for more than one year. For individuals, the excess of net long-term capital
gains over net short-term capital losses generally is taxed at a lower rate than
ordinary income. The distinction between capital gain or loss and ordinary
income or loss is also relevant for purposes of, among other things, limitations
on the deductibility of capital losses.
NON-U.S. HOLDERS
INTEREST AND DISPOSITION OF NOTES
Subject to the discussion below concerning backup withholding, principal
and interest payments made on, and gains from the sale, exchange or other
disposition of, an exchange note will not be subject to the withholding of
federal income tax, provided that, in the case of interest,
o the Non-U.S. Holder does not own, actually or constructively, 10% or
more of the total combined voting power of all classes of voting stock
of the issuer,
o the Non-U.S. Holder is not a controlled foreign corporation related,
directly or indirectly, to the issuer through stock ownership,
o the Non-U.S. Holder is not a bank receiving interest described in
section 881(c)(3)(A) of the Code, and
o the certification requirements under section 871(h) or section 881(c)
of the Code and the Treasury Regulations thereunder, summarized below,
are met.
Sections 871(h) and 881(c) of the Code and Treasury Regulations thereunder
require that, in order to obtain the exemption from withholding described above,
either
o the beneficial owner of the exchange note must certify, under
penalties of perjury, to the withholding agent that such owner is a
Non-U.S. Holder and must provide such owner's name, address and United
States taxpayer identification number, if any, and otherwise satisfy
documentary evidence requirements,
o a financial institution that holds customers' securities in the
ordinary course of business and holds an exchange note must certify to
the withholding agent that appropriate certification has been received
from the beneficial owner by it or by a financial institution between
it and the beneficial owner and generally furnish the withholding
agent with a copy thereof, or
o the Non-U.S. Holder must provide such certification to a "qualified
intermediary" or a "withholding foreign partnership" and certain other
conditions must be met.
A Non-U.S. Holder may give the certification described above on IRS Form
W-8BEN, which generally is effective for the remainder of the year of signature
plus three full calendar years, unless a change in circumstances make any
information on the form incorrect. Special rules apply to foreign partnerships.
In general, the foreign partnership will be required to provide a properly
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executed IRS Form W-8IMY and attach thereto an appropriate certification from
each partner. Partners in foreign partnerships are urged to consult their tax
advisors.
Even if a Non-U.S. Holder does not meet the above requirements, interest
payments will not be subject to the withholding of federal income tax if the
Non-U.S. Holder certifies that either (i) an applicable tax treaty exempts, or
provides for a reduction in, withholding or (ii) interest paid on an exchange
note is effectively connected with the holder's trade or business in the U.S.
and therefore is not subject to withholding (as described in greater detail
below).
If a Non-U.S. Holder is engaged in a trade or business in the United
States, and if interest on an exchange note is effectively connected with the
conduct of such trade or business, the Non-U.S. Holder, although exempt from
withholding of federal income tax, will generally be subject to regular federal
income tax on such interest in the same manner as if he or she were a U.S.
Holder. In lieu of providing an IRS Form W-8BEN, such a Non-U.S. Holder will be
required to provide the withholding agent with a properly executed IRS Form
W-8ECI in order to claim an exemption from withholding. In addition, if such
Non-U.S. Holder is a foreign corporation, it may be subject to branch profits
tax equal to 30%, or such lower rate as may be provided by an applicable treaty,
of its effectively connected earnings and profits for the taxable year, subject
to certain adjustments.
A Non-U.S. Holder will not be subject to federal income tax on any gain
realized on the sale, exchange or disposition of an exchange note (except to the
extent that such gain is attributable to accrued but unpaid interest) unless the
gain is effectively connected with such holder's trade or business in the United
States or, if the holder is an individual, such holder is present in the United
States for 183 days or more in the taxable year of the sale, exchange or
disposition and certain other conditions are met. The branch profits tax
described above may apply to gain effectively connected with a United States
trade or business of a foreign corporation.
BACKUP WITHHOLDING AND INFORMATION REPORTING
U.S. Holders. Information reporting requirements apply to interest and
principal payments made to, and to the proceeds of sales before maturity by,
certain non-corporate U.S. Holders. In addition, backup withholding is required
unless a U.S. Holder furnishes a correct taxpayer identification number (which
for an individual is the Social Security Number) and certifies, under penalties
of perjury, that he or she is not subject to backup withholding on an IRS Form
W-9 and otherwise complies with applicable requirements of the backup
withholding rules. The current rate of backup withholding is 28% of the amount
paid. Backup withholding does not apply with respect to payments made to certain
exempt recipients, such as corporations and tax-exempt organizations. Any
amounts withheld under the backup withholding rules may be allowed as a credit
against the U.S. Holder's federal income tax liability, provided that the
required information is furnished to the IRS.
Non-U.S. Holders. Backup withholding tax does not apply to payments of
interest and principal made to, and the proceeds of sales before maturity by, a
Non-U.S. Holder if such Non-U.S. Holder certifies (on Form IRS W-8BEN or other
appropriate form) its Non-U.S. Holder status. However, information reporting on
IRS Form 1042-S will generally apply to payments of interest. Information
reporting may also apply to payments made outside the United States, and
payments on the sale, exchange, redemption, retirement or other disposition of a
debt security effected outside the United States, if payment is made by a payor
that is, for federal income tax purposes,
o a United States person,
o a controlled foreign corporation,
o a United States branch of a foreign bank or foreign insurance company,
o a foreign partnership controlled by United States persons or engaged
in a United States trade or business, or
o a foreign person, 50% or more of whose gross income is effectively
connected with the conduct of a United States trade or business for a
specified three-year period,
unless such payor has in its records documentary evidence that the beneficial
owner is not a U.S. Holder and certain other conditions are met or the
beneficial owner otherwise establishes an exemption.
Any amounts withheld under the backup withholding rules may be allowed as a
credit against an exchange noteholder's federal income tax liability, provided
that the required information is furnished to the IRS.
THE UNITED STATES FEDERAL INCOME TAX DISCUSSION SET FORTH ABOVE IS INCLUDED
FOR GENERAL INFORMATION ONLY AND MAY NOT BE APPLICABLE DEPENDING UPON A HOLDER'S
PARTICULAR SITUATION. HOLDERS CONSIDERING EXCHANGING OUTSTANDING NOTES FOR
EXCHANGE NOTES SHOULD CONSULT THEIR OWN TAX ADVISORS WITH RESPECT TO THE TAX
CONSEQUENCES TO
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THEM OF THE ACQUISITION, OWNERSHIP AND DISPOSITION OF EXCHANGE NOTES, INCLUDING
THE TAX CONSEQUENCES UNDER STATE, LOCAL, ESTATE, FOREIGN AND OTHER TAX LAWS AND
THE POSSIBLE EFFECTS OF CHANGES IN UNITED STATES OR OTHER TAX LAWS.
PLAN OF DISTRIBUTION
Each broker-dealer that receives exchange notes for its own account
pursuant to the exchange offer must acknowledge that it will deliver a
prospectus in connection with any resale of such exchange notes. This
Prospectus, as it may be amended or supplemented from time to time, may be used
by a broker-dealer in connection with resales of exchange notes received in
exchange for outstanding notes where such outstanding notes were acquired as a
result of market-making activities or other trading activities. We have agreed
that, for a period of 180 days after the expiration date, we will make this
prospectus, as amended or supplemented, available to any broker-dealer for use
in connection with any such resale. In addition, until October 22, 2003, all
dealers effecting transactions in the exchange notes may be required to deliver
a prospectus.
We will not receive any proceeds from any sale of exchange notes by
broker-dealers. Exchange notes received by broker-dealers for their own account
pursuant to the exchange offer may be sold from time to time in one or more
transactions in the over-the-counter market, in negotiated transactions, through
the writing of options on the exchange notes or a combination of such methods of
resale, at market prices prevailing at the time of resale, at prices related to
such prevailing market prices or negotiated prices. Any such resale may be made
directly to purchasers or to or through brokers or dealers who may receive
compensation in the form of commissions or concessions from any such
broker-dealer or the purchasers of any such exchange notes. Any broker-dealer
that resells exchange notes that were received by it for its own account
pursuant to the exchange offer and any broker or dealer that participates in a
distribution of such exchange notes may be deemed to be an "underwriter" within
the meaning of the Securities Act and any profit on any such resale of exchange
notes and any commission or concessions received by any such persons may be
deemed to be underwriting compensation under the Securities Act. The Letter of
Transmittal states that, by acknowledging that it will deliver and by delivering
a prospectus, a broker-dealer will not be deemed to admit that it is an
"underwriter" within the meaning of the Securities Act.
For a period of 180 days after the expiration date, we will promptly send
additional copies of this Prospectus and any amendment or supplement to this
Prospectus to any broker-dealer that requests such documents in the Letter of
Transmittal. We have agreed to pay all expenses incident to the exchange offer
(including the expenses of one counsel for the Holders of the Securities) other
than commissions or concessions of any broker or dealers and will indemnify the
Holders of the exchange notes (including any broker-dealers) against certain
liabilities, including liabilities under the Securities Act.
LEGAL MATTERS
Certain legal matters with respect to the validity of the exchange notes
offered hereby will be passed upon for us by Sidley Austin Brown & Wood LLP,
Chicago, Illinois.
EXPERTS
The financial statements of CITGO Petroleum Corporation as of December 31,
2002 and 2001, and for each of the three years in the period ended December 31,
2002, included in this prospectus have been audited by Deloitte & Touche LLP,
independent auditors, as stated in their report appearing herein, which report
expresses an unqualified opinion and includes an explanatory paragraph referring
to the retroactive restatement of the financial statements to give effect to the
January 1, 2002 contribution by PDV America of VPHI stock to us, which has been
accounted for in a manner similar to "pooling of interests" accounting, and have
been so included in reliance upon the report of such firm given upon their
authority as experts in accounting and auditing.
The financial statements of LYONDELL-CITGO Refining LP as of December
31, 2002 and 2001 and for each of the three years in the period ended December
31, 2002 included in this prospectus have been so included in reliance on the
report of PricewaterhouseCoopers LLP, independent accountants, given on the
authority of said firm as experts in auditing and accounting.
WHERE YOU CAN FIND MORE INFORMATION
We file annual, quarterly and current reports and other information with
the SEC. These reports include as exhibits copies of material documents and
agreements described in this prospectus, including our supply agreements with
PDVSA. You may read and copy any document that we file with the SEC at the
Public Reference Room of the SEC at 450 Fifth Street, N.W. Washington, D.C.
20549. Information on the operation of the Public Reference Room may be obtained
by calling the SEC at 1-800-SEC-0330. Our SEC filings are also available to the
public over the Internet on the SEC's web site at http://www.sec.gov. You can
inspect reports and other information we file at the offices of the New York
Stock Exchange, Inc., 20 Broad Street, New York, New York 10005. You may also
obtain these reports at no cost by writing us at CITGO Petroleum Corporation,
One Warren Place, 6100 South Yale Avenue, Tulsa, Oklahoma 74136, Attention:
Corporate Secretary (telephone: (918) 495-4589).
109
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
PAGE NO.
--------
Audited Financial Statements of CITGO Petroleum Corporation
Independent Auditors' Report................................... F-2
Consolidated Balance Sheets as of December 31, 2002 and
2001........................................................ F-3
Consolidated Statements of Income and Comprehensive
Income -- Each of the Three Years in the Period Ended
December 31, 2002........................................... F-4
Consolidated Statements of Shareholder's Equity -- Each
of the Three Years in the Period Ended December 31,
2002........................................................ F-5
Consolidated Statements of Cash Flows -- Each of the
Three Years in the Period Ended December 31, 2002........... F-6
Notes to Consolidated Financial Statements -- Each of the
Three Years in the Period Ended December 31, 2002........... F-8
Audited Financial Statements of LYONDELL-CITGO Refining LP
Report of Independent Accountants.............................. F-39
Statements of Income for the Years Ended December 31,
2002, 2001 and 2000......................................... F-40
Balance Sheets as of December 31, 2002 and 2001................ F-41
Statements of Cash Flows for the Years Ended December 31,
2002, 2001 and 2000......................................... F-42
Statements of Partners' Capital................................ F-43
Notes to Financial Statements.................................. F-44
F-1
INDEPENDENT AUDITORS' REPORT
To the Board of Directors and Shareholder of
CITGO Petroleum Corporation:
We have audited the accompanying consolidated balance sheets of CITGO Petroleum
Corporation and subsidiaries as of December 31, 2002 and 2001, and the related
consolidated statements of income and comprehensive income, shareholder's equity
and cash flows for each of the three years in the period ended December 31,
2002. 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 of America. 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, such consolidated financial statements present fairly, in all
material respects, the financial position of CITGO Petroleum Corporation and
subsidiaries at December 31, 2002 and 2001, and the results of their operations
and their cash flows for each of the three years in the period ended December
31, 2002 in conformity with accounting principles generally accepted in the
United States of America.
As discussed in Note 17, the accompanying consolidated financial statements for
2001 and 2000 have been restated to give retroactive effect to the January 1,
2002 merger of CITGO Petroleum Corporation and VPHI Midwest, Inc., which has
been accounted for in a manner similar to "pooling-of-interests" accounting.
DELOITTE & TOUCHE LLP
Tulsa, Oklahoma
February 14, 2003
F-2
CITGO PETROLEUM CORPORATION
CONSOLIDATED BALANCE SHEETS
(DOLLARS IN THOUSANDS)
DECEMBER 31,
---------------------------
2002 2001
(AS RESTATED
- SEE NOTE 17)
---------------------------
ASSETS
CURRENT ASSETS:
Cash and cash equivalents $ 33,025 $ 104,362
Accounts receivable, net 905,178 913,068
Due from affiliates 93,615 64,923
Inventories 1,090,915 1,109,346
Prepaid expenses and other 64,767 95,334
----------- -----------
Total current assets 2,187,500 2,287,033
PROPERTY, PLANT AND EQUIPMENT - Net 3,750,166 3,292,469
RESTRICTED CASH 23,486 -
INVESTMENTS IN AFFILIATES 716,469 700,701
OTHER ASSETS 309,291 228,906
----------- -----------
$ 6,986,912 $ 6,509,109
=========== ===========
LIABILITIES AND SHAREHOLDER'S EQUITY
CURRENT LIABILITIES:
Accounts payable 830,769 616,854
Payables to affiliates 417,634 265,517
Taxes other than income 229,072 219,699
Other 308,198 300,484
Current portion of long-term debt 190,664 107,864
Current portion of capital lease obligation 22,713 20,358
----------- -----------
Total current liabilities 1,999,050 1,530,776
LONG-TERM DEBT 1,109,861 1,303,692
CAPITAL LEASE OBLIGATION 24,251 46,964
POSTRETIREMENT BENEFITS OTHER THAN PENSIONS 247,762 218,706
OTHER NONCURRENT LIABILITIES 211,950 217,121
DEFERRED INCOME TAXES 834,880 767,338
MINORITY INTEREST - 23,176
COMMITMENTS AND CONTINGENCIES (Note 14)
SHAREHOLDER'S EQUITY:
Common stock - $1.00 par value, 1,000 shares authorized, issued and outstanding 1 1
Additional capital 1,659,698 1,659,698
Retained earnings 925,114 745,102
Accumulated other comprehensive loss (25,655) (3,465)
----------- -----------
Total shareholder's equity 2,559,158 2,401,336
----------- -----------
$ 6,986,912 $ 6,509,109
=========== ===========
See notes to consolidated financial statements
F-3
CITGO PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
EACH OF THE THREE YEARS IN THE PERIOD ENDED DECEMBER 31, 2002
(DOLLARS IN THOUSANDS)
2002 2001 2000
(AS RESTATED - SEE NOTE 17)
REVENUES:
Net sales $ 19,080,845 $ 19,343,263 $ 21,941,263
Sales to affiliates 277,477 257,905 215,965
------------ ------------ ------------
19,358,322 19,601,168 22,157,228
Equity in earnings of affiliates 101,326 108,915 58,728
Insurance recoveries 406,570 52,868 -
Other income (expense), net (19,735) (58,103) (26,011)
------------ ------------ ------------
19,846,483 19,704,848 22,189,945
------------ ------------ ------------
COST OF SALES AND EXPENSES:
Cost of sales and operating expenses (including purchases of
$6,779,798, $6,558,203 and $8,676,970 from affiliates) 19,211,316 18,734,652 21,370,315
Selling, general and administrative expenses 284,871 292,127 226,601
Interest expense, excluding capital lease 67,394 69,164 85,565
Capital lease interest charge 7,017 9,128 11,019
Minority interest - 1,971 1,808
------------ ------------ ------------
19,570,598 19,107,042 21,695,308
------------ ------------ ------------
INCOME BEFORE INCOME TAXES AND CUMULATIVE
EFFECT OF CHANGE IN ACCOUNTING PRINCIPLE 275,885 597,806 494,637
INCOME TAXES 95,873 206,222 182,627
------------ ------------ ------------
INCOME BEFORE CUMULATIVE EFFECT OF CHANGE
IN ACCOUNTING PRINCIPLE 180,012 391,584 312,010
CUMULATIVE EFFECT, ACCOUNTING FOR DERIVATIVES,
NET OF RELATED INCOME TAXES OF $7,977 - 13,600 -
------------ ------------ ------------
NET INCOME 180,012 405,184 312,010
OTHER COMPREHENSIVE INCOME (LOSS):
Cash flow hedges:
Cumulative effect, accounting for derivatives, net of related
income taxes of $(850) - (1,450) -
Less: reclassification adjustment for derivative losses included in
net income, net of related income taxes of $182 in 2002 and $265 in 2001 310 469 -
------------ ------------ ------------
310 (981) -
Foreign currency translation loss, net of related
income taxes of $(78) (172) - -
Minimum pension liability adjustment, net of deferred taxes of $12,835 in
2002, $69 in 2001 and $(499) in 2000 (22,328) (119) 849
------------ ------------ ------------
Total other comprehensive (loss) income (22,190) (1,100) 849
------------ ------------ ------------
COMPREHENSIVE INCOME $ 157,822 $ 404,084 $ 312,859
============ ============ ============
F-4
CITGO PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF SHAREHOLDER'S EQUITY
EACH OF THE THREE YEARS IN THE PERIOD ENDED DECEMBER 31, 2002
(DOLLARS AND SHARES IN THOUSANDS)
ACCUMULATED OTHER
COMPREHENSIVE INCOME (LOSS)
---------------------------------------
COMMON STOCK MINIMUM FOREIGN CASH TOTAL
-------------- ADDITIONAL RETAINED PENSION CURRENCY FLOW SHAREHOLDER'S
SHARES AMOUNT CAPITAL EARNINGS LIABILITY TRANSLATION HEDGES TOTAL EQUITY
BALANCE, JANUARY 1, 2000
(As restated - See Note 17) 1 $ 1 $1,667,305 $ 721,020 $ (3,214) $ - $ - $ (3,214) $ 2,385,112
Net income - - - 312,010 - - - - 312,010
Other comprehensive income - - - - 849 - - 849 849
Tax allocation agreement
amendment - - (7,607) 10,788 - - - - 3,181
Dividend paid - - - (225,000) - - - - (225,000)
--- --- ---------- --------- -------- ----- ----- -------- -----------
BALANCE, DECEMBER 31, 2000
(As restated - See Note 17) 1 1 1,659,698 818,818 (2,365) - - (2,365) 2,476,152
Net income - - - 405,184 - - - - 405,184
Other comprehensive loss - - - - (119) - (981) (1,100) (1,100)
Dividend paid - - - (478,900) - - - - (478,900)
--- --- ---------- --------- -------- ----- ----- ------- ----------
BALANCE, DECEMBER 31, 2001
(As restated - See Note 17) 1 1 1,659,698 745,102 (2,484) - (981) (3,465) 2,401,336
Net income - - - 180,012 - - - - 180,012
Other comprehensive (loss) income - - - - (22,328) (172) 310 (22,190) (22,190)
--- --- ---------- --------- -------- ----- ----- -------- -----------
BALANCE, DECEMBER 31, 2002 1 $ 1 $1,659,698 $ 925,114 $(24,812) $(172) $(671) $(25,655) $ 2,559,158
=== === ========== ========= ======== ===== ===== ======== ===========
See notes to consolidated financial statements.
F-5
CITGO PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
EACH OF THE THREE YEARS IN THE PERIOD ENDED DECEMBER 31, 2002
(DOLLARS IN THOUSANDS)
2002 2001 2000
(AS RESTATED - SEE NOTE 17)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income $ 180,012 $ 405,184 $ 312,010
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation and amortization 298,686 288,882 290,450
Provision for losses on accounts receivable 17,458 6,239 1,651
Loss on sale of investments - - 1
Deferred income taxes 37,642 115,025 52,945
Distributions in excess of equity in earnings of affiliates 22,313 44,521 68,196
Other adjustments 3,992 24,680 26,260
Changes in operating assets and liabilities:
Accounts receivable and due from affiliates (40,009) 427,771 (348,229)
Inventories 18,431 42,960 (58,142)
Prepaid expenses and other current assets 62,465 (84,280) 550
Accounts payable and other current liabilities 315,266 (625,313) 512,753
Other assets (128,466) (90,984) (52,550)
Other liabilities 30,483 29,802 (2,609)
--------- --------- ---------
Total adjustments 638,261 179,303 491,276
--------- --------- ---------
Net cash provided by operating activities 818,273 584,487 803,286
--------- --------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures (711,834) (253,465) (122,049)
Proceeds from sales of property, plant and equipment 919 3,866 4,491
(Increase) decrease in restricted cash (23,486) - 3,015
Investments in LYONDELL-CITGO Refining LP (32,000) (31,800) (17,600)
Loans to LYONDELL-CITGO Refining LP - - (7,024)
Investments in and advances to other affiliates (22,484) (11,435) (14,500)
--------- --------- ---------
Net cash used in investing activities (788,885) (292,834) (153,667)
--------- --------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES:
Net (repayments of) proceeds from short-term bank loans - (37,500) 21,500
Net (repayments of) proceeds from revolving bank loans (112,200) 391,500 (462,000)
Proceeds from loans from affiliates 39,000 - -
Payments on private placement senior notes (11,364) (39,935) (39,935)
Payments of master shelf agreement notes (25,000) - -
Payments on taxable bonds (31,000) (28,000) -
Proceeds from issuance of tax-exempt bonds 68,502 28,000 -
Payments of capital lease obligations (20,358) (26,649) (7,954)
Repayments of other debt (8,305) (14,845) (14,179)
Dividends paid - (478,900) (225,000)
--------- --------- ---------
Net cash used in financing activities (100,725) (206,329) (727,568)
--------- --------- ---------
(Continued)
F-6
CITGO PETROLEUM CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
EACH OF THE THREE YEARS IN THE PERIOD ENDED DECEMBER 31, 2002
(DOLLARS IN THOUSANDS)
2002 2001 2000
(AS RESTATED - SEE NOTE 17)
(DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS $ (71,337) $ 85,324 $ (77,949)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD 104,362 19,038 96,987
--------- --------- ---------
CASH AND CASH EQUIVALENTS, END OF PERIOD $ 33,025 $ 104,362 $ 19,038
========= ========= =========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest, net of amounts capitalized $ 72,970 $ 83,972 $ 92,080
========= ========= =========
Income taxes, net of refunds of $50,733 in 2002 $ (45,745) $ 296,979 $ 60,501
========= ========= =========
SUPPLEMENTAL SCHEDULE OF NONCASH FINANCING ACTIVITIES:
Tax allocation agreement amendment $ - $ - $ 3,181
========= ========= =========
See notes to consolidated financial statements. (Concluded)
F-7
CITGO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (AS RESTATED - SEE NOTE 17)
EACH OF THE THREE YEARS IN THE PERIOD ENDED DECEMBER 31, 2002
1. SIGNIFICANT ACCOUNTING POLICIES
DESCRIPTION OF BUSINESS - CITGO Petroleum Corporation ("CITGO") is a
subsidiary of PDV America, Inc. ("PDV America"), an indirect wholly owned
subsidiary of Petroleos de Venezuela, S.A. ("PDVSA"), the national oil
company of the Bolivarian Republic of Venezuela.
CITGO manufactures or refines and markets quality transportation fuels as
well as lubricants, refined waxes, petrochemicals, asphalt and other
industrial products. CITGO owns and operates three modern, highly complex
crude oil refineries (Lake Charles, Louisiana, Corpus Christi, Texas, and
Lemont, Illinois) and two asphalt refineries (Paulsboro, New Jersey, and
Savannah, Georgia) with a combined aggregate rated crude oil refining
capacity of 756 thousand barrels per day ("MBPD"). CITGO also owns a
minority interest in LYONDELL-CITGO Refining LP, a limited partnership
(formerly a limited liability company) that owns and operates a refinery
in Houston, Texas, with a rated crude oil refining capacity of 265 MBPD.
CITGO's consolidated financial statements also include accounts relating
to a lubricant and wax plant, pipelines, and equity interests in pipeline
companies and petroleum storage terminals.
CITGO's transportation fuel customers include primarily CITGO branded
wholesale marketers, convenience stores and airlines located mainly east
of the Rocky Mountains. Asphalt is generally marketed to independent
paving contractors on the East and Gulf Coasts and the Midwest of the
United States. Lubricants are sold principally in the United States to
independent marketers, mass marketers and industrial customers.
Petrochemical feedstocks and industrial products are sold to various
manufacturers and industrial companies throughout the United States.
Petroleum coke is sold primarily in international markets. CITGO is also
engaged in an effort to sell lubricants, gasoline and distillates in
various Latin American markets.
PRINCIPLES OF CONSOLIDATION - The condensed consolidated financial
statements include the accounts of CITGO and its subsidiaries including
VPHI Midwest, Inc. ("VPHI" - See Note 17 "Change in Reporting Entity") and
its wholly owned subsidiary, PDV Midwest Refining, L.L.C. ("PDVMR"), and
Cit-Con Oil Corporation ("Cit-Con"), which was 65 percent owned by CITGO
through December 31, 2001 (collectively referred to as the "Company"). On
January 1, 2002, CITGO acquired the outstanding 35 percent interest in
Cit-Con from Conoco, Inc. The principal asset of Cit-Con is a lubricants
and wax plant in Lake Charles, Louisiana. This transaction did not have a
material effect on the consolidated financial position or results of
operations of the Company. The legal entity, Cit-Con Oil Corporation, was
dissolved effective April 1, 2002. All subsidiaries are wholly owned. All
material intercompany transactions and accounts have been eliminated.
The Company's investments in less than majority-owned affiliates are
accounted for by the equity method. The excess of the carrying value of
the investments over the equity in the underlying net assets of the
affiliates is amortized on a straight-line basis over 40 years, which is
based upon the estimated useful lives of the affiliates' assets.
F-8
ESTIMATES, RISKS AND UNCERTAINTIES - The preparation of financial
statements in conformity with accounting principles generally accepted in
the United States of America requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the
financial statements and the reported amounts of revenues and expenses
during the reporting period. Actual results could differ from those
estimates.
CITGO's operations can be influenced by domestic and international
political, legislative, regulatory and legal environments. In addition,
significant changes in the prices or availability of crude oil and refined
products could have a significant impact on CITGO's results of operations
for any particular year.
IMPAIRMENT OF LONG-LIVED ASSETS - The Company periodically evaluates the
carrying value of long-lived assets to be held and used when events and
circumstances warrant such a review. The carrying value of a long-lived
asset is considered impaired when the separately identifiable anticipated
undiscounted net cash flow from such asset is less than its carrying
value. In that event, a loss is recognized based on the amount by which
the carrying value exceeds the fair value of the long-lived asset. Fair
value is determined primarily using the anticipated net cash flows
discounted at a rate commensurate with the risk involved. Losses on
long-lived assets to be disposed of are determined in a similar manner,
except that fair values are reduced for disposal costs.
REVENUE RECOGNITION - Revenue is generated from the sale of refined
petroleum products to bulk purchasers, wholesale purchasers and final
consumers. CITGO's transportation fuel customers include primarily CITGO
branded wholesale marketers, convenience stores and airlines located
mainly east of the Rocky Mountains. Asphalt is generally marketed to
independent paving contractors on the East and Gulf Coasts and the Midwest
of the United States. Lubricants are sold principally in the United States
to independent marketers, mass marketers and industrial customers.
Petrochemical feedstocks and industrial products are sold to various
manufacturers and industrial companies throughout the United States.
Petroleum coke is sold primarily in international markets. CITGO is also
engaged in an effort to sell lubricants, gasoline and distillates in
various Latin American markets.
Revenue recognition occurs at the point that title to the refined
petroleum product is transferred to the customer. That transfer is
determined from the delivery terms of the customer's contract. In the case
of bulk purchasers, delivery and title transfer may occur while the
refined petroleum products are in transit, if agreed by the purchaser; or
may occur when the hydrocarbons are transferred into a storage facility at
the direction of the purchaser. In the case of wholesale purchasers,
delivery and title transfer generally occurs when the refined petroleum
products are transferred from a storage facility to the transport truck.
Direct sales to the final consumer make up an immaterial portion of
revenue recognized by CITGO.
SUPPLY AND MARKETING ACTIVITIES - The Company engages in the buying and
selling of crude oil to supply its refineries. The net results of this
activity are recorded in cost of sales. The Company also engages in the
buying and selling of refined products to facilitate the marketing of its
refined products. The results of this activity are recorded in cost of
sales and sales.
Refined product exchange transactions that do not involve the payment or
receipt of cash are not accounted for as purchases or sales. Any resulting
volumetric exchange balances are accounted for as inventory in accordance
with the Company's last-in, first-out ("LIFO") inventory method. Exchanges
that are settled through payment or receipt of cash are accounted for as
purchases or sales.
EXCISE TAXES - The Company collects excise taxes on sales of gasoline and
other motor fuels. Excise taxes of approximately $3.2 billion, $3.3
billion, and $3.2 billion were collected from customers and
F-9
paid to various governmental entities in 2002, 2001, and 2000,
respectively. Excise taxes are not included in sales.
CASH AND CASH EQUIVALENTS - Cash and cash equivalents consist of highly
liquid short-term investments and bank deposits with initial maturities of
three months or less.
INVENTORIES - Crude oil and refined product inventories are stated at the
lower of cost or market and cost is determined using the LIFO method.
Materials and supplies are valued using the average cost method.
PROPERTY, PLANT AND EQUIPMENT - Property, plant and equipment is reported
at cost, less accumulated depreciation. Depreciation is based upon the
estimated useful lives of the related assets using the straight-line
method. Depreciable lives are generally as follows: buildings and
leaseholds - 10 to 24 years; machinery and equipment - 5 to 24 years; and
vehicles - 3 to 10 years.
Upon disposal or retirement of property, plant and equipment, the cost and
related accumulated depreciation are removed from the accounts and any
resulting gain or loss is recognized in income.
The Company capitalizes interest on projects when construction entails
major expenditures over extended time periods. Such interest is allocated
to property, plant and equipment and amortized over the estimated useful
lives of the related assets. Interest capitalized totaled $4 million, $2
million, and $4 million, during 2002, 2001, and 2000, respectively.
RESTRICTED CASH - The Company has restricted cash of $23 million at
December 31, 2002 consisting of highly liquid investments held in trust
accounts in accordance with tax exempt revenue bonds due 2032. Funds are
released solely for financing the qualified capital expenditures as
defined in the bond agreement.
COMMODITY AND INTEREST RATE DERIVATIVES - The Company enters into
petroleum futures contracts, options and other over-the-counter commodity
derivatives, primarily to reduce its inventory purchase and product sale
exposure to market risk. In the normal course of business, the Company
also enters into certain petroleum commodity forward purchase and sale
contracts, which qualify as derivatives. The Company also enters into
various interest rate swap agreements to manage its risk related to
interest rate change on its debt.
In June 1998, the Financial Accounting Standards Board ("FASB") issued
Statement of Financial Accounting Standards No. 133, "Accounting for
Derivative Instruments and Hedging Activities" ("SFAS No. 133"). In June
2000, Statement of Financial Accounting Standards No. 138, "Accounting for
Certain Derivative Instruments and Certain Hedging Activities, an
amendment of SFAS No. 133," was issued. The statement, as amended,
establishes accounting and reporting standards for derivative instruments
and for hedging activities. It requires that an entity recognize all
derivatives, at fair value, as either assets or liabilities in the
statement of financial position with an offset either to shareholder's
equity and comprehensive income or income depending upon the
classification of the derivative. The Company adopted SFAS No. 133 on
January 1, 2001. Certain of the derivative instruments identified at
January 1, 2001 under the provisions of SFAS No. 133 had been previously
designated in hedging relationships that addressed the variable cash flow
exposure of forecasted transactions; under the transition provisions of
SFAS No. 133, on January 1, 2001 the Company recorded an after-tax,
cumulative-effect-type transition charge of $1.5 million to accumulated
other comprehensive income related to these derivatives. Certain of the
derivative instruments identified at January 1, 2001, under the provisions
of SFAS No. 133 had been previously designated in hedging relationships
that addressed the fair value of certain forward purchase and sale
commitments; under the transition provisions of SFAS No. 133, on January
1, 2001 the Company recorded fair value adjustments to the subject
derivatives and
F-10
related commitments resulting in the recording of a net after-tax,
cumulative-effect-type transition charge of $0.2 million to net income.
The remaining derivatives identified at January 1, 2001 under the
provisions of SFAS No. 133, consisting of certain forward purchases and
sales, had not previously been considered derivatives under accounting
principles generally accepted in the United States of America; under the
transition provisions of SFAS No. 133, on January 1, 2001 the Company
recorded an after-tax, cumulative-effect-type benefit of $13.8 million to
net income related to these derivatives. The Company did not elect
prospective hedge accounting for derivatives existing at the date of
adoption of SFAS No. 133.
Effective January 1, 2001, fair values of derivatives are recorded in
other current assets or other current liabilities, as applicable, and
changes in the fair value of derivatives not designated in hedging
relationships are recorded in income. Effective January 1, 2001, the
Company's policy is to elect hedge accounting only under limited
circumstances involving derivatives with initial terms of 90 days or
greater and notional amounts of $25 million or greater.
Prior to January 1, 2001, gains or losses on contracts which qualified as
hedges were recognized when the related inventory was sold or the hedged
transaction was consummated. Changes in the market value of commodity
derivatives which were not hedges were recorded as gains or losses in the
period in which they occurred. Additionally, prior to January 1, 2001,
premiums paid for purchased interest rate swap agreements were amortized
to interest expense over the terms of the agreements. Unamortized premiums
were included in other assets. The interest rate differentials received or
paid by the Company related to these agreements were recognized as
adjustments to interest expense over the term of the agreements.
REFINERY MAINTENANCE - Costs of major refinery turnaround maintenance are
charged to operations over the estimated period between turnarounds.
Turnaround periods range approximately from one to seven years.
Unamortized costs are included in other assets. Amortization of refinery
turnaround costs is included in depreciation and amortization expense.
Amortization was $75 million, $69 million, and $68 million for 2002, 2001,
and 2000, respectively. Ordinary maintenance is expensed as incurred.
The American Institute of Certified Public Accountants has issued a
"Statement of Position" exposure draft on cost capitalization that is
expected to require companies to expense the non-capital portion of major
maintenance costs as incurred. The statement is expected to require that
any existing unamortized deferred non-capital major maintenance costs be
expensed immediately. The exposure draft indicates that this change will
be required to be adopted for fiscal years beginning after June 15, 2003,
and that the effect of expensing existing unamortized deferred non-capital
major maintenance costs will be reported as a cumulative effect of an
accounting change in the consolidated statement of income. Currently, the
AICPA is discussing the future of this exposure draft with the FASB. The
final accounting requirements and timing of required adoption are not
known at this time. At December 31, 2002, the Company had included
turnaround costs of $210 million in other assets. Company management has
not determined the amount, if any, of these costs that could be
capitalized under the provisions of the exposure draft.
ENVIRONMENTAL EXPENDITURES - Environmental expenditures that relate to
current or future revenues are expensed or capitalized as appropriate.
Expenditures that relate to an existing condition caused by past
operations and that do not contribute to current or future revenue
generation are expensed. Liabilities are recorded when environmental
assessments and/or cleanups are probable and the costs can be reasonably
estimated. Environmental liabilities are not discounted to their present
value and are recorded without consideration of potential recoveries from
third parties. Subsequent adjustments to estimates, to the extent
required, may be made as more refined information becomes available.
F-11
INCOME TAXES - The Company is included in the consolidated U.S. federal
income tax return filed by PDV Holding, Inc., the direct parent of PDV
America. The Company's current and deferred income tax expense has been
computed on a stand-alone basis using an asset and liability approach.
NEW ACCOUNTING STANDARDS - In July 2001, the FASB issued Statement of
Financial Accounting Standards No. 142, "Goodwill and Other Intangible
Assets" ("SFAS No. 142") which is fully effective in fiscal years
beginning after December 15, 2001, although certain provisions of SFAS No.
142 are applicable to goodwill and other intangible assets acquired in
transactions completed after June 30, 2001. SFAS No. 142 addresses
financial accounting and reporting for acquired goodwill and other
intangible assets and requires that goodwill and intangibles with an
indefinite life no longer be amortized but instead be periodically
reviewed for impairment. The adoption of SFAS No. 142 did not materially
impact the Company's financial position or results of operations.
On January 1, 2003 the Company adopted Statement of Financial Accounting
Standards No. 143, "Accounting for Asset Retirement Obligations" (SFAS No.
143) which addresses financial accounting and reporting for obligations
associated with the retirement of tangible long-lived assets and the
associated asset retirement costs. It applies to legal obligations
associated with the retirement of long-lived assets that result from the
acquisition, construction, development and/or the normal operation of a
long-lived asset, except for certain obligations of lessees. The Company
has identified certain asset retirement obligations that are within the
scope of the standard, including obligations imposed by certain state laws
pertaining to closure and/or removal of storage tanks, contractual removal
obligations included in certain easement and right-of-way agreements
associated with the Company's pipeline operations, and contractual removal
obligations relating to a refinery processing unit located within a
third-party entity's facility. The Company cannot currently determine a
reasonable estimate of the fair value of its asset retirement obligations
due to the fact that the related assets have indeterminate useful lives
which preclude development of assumptions about the potential timing of
settlement dates. Such obligations will be recognized in the period in
which sufficient information exists to estimate a range or potential
settlement dates. Accordingly, the adoption of SFAS No. 143 did not impact
the Company's financial position or results of operations.
In August 2001, the FASB issued Statement of Financial Accounting
Standards No. 144, "Accounting for the Impairment or Disposal of
Long-Lived Assets" ("SFAS No. 144") which addresses financial accounting
and reporting for the impairment or disposal of long-lived assets by
requiring that one accounting model be used for long-lived assets to be
disposed of by sale, whether previously held and used or newly acquired,
and by broadening the presentation of discontinued operations to include
more disposal transactions. SFAS No. 144 is effective for financial
statements issued for fiscal years beginning after December 15, 2001, and
interim periods within those fiscal years. The provisions of this
statement generally are to be applied prospectively; therefore, the
adoption of SFAS No. 144 did not impact the Company's financial position
or results of operations.
In November 2002, the FASB issued Interpretation No. 45, "Guarantor's
Accounting and Disclosure Requirements for Guarantees, Including Indirect
Guarantees of Indebtedness of Others." This interpretation elaborates on
the disclosures to be made by a guarantor in its financial statements
about its obligations under certain guarantees that it has issued. It also
requires a guarantor to recognize, at the inception of a guarantee, a
liability for the fair value of the obligations it has undertaken in
issuing the guarantee. The initial recognition and initial measurement
provisions of the interpretation are applicable on a prospective basis to
guarantees issued or modified after December 31, 2002. The disclosure
requirements are effective for financial statements of interim or annual
periods ending after December 15, 2002. (See Note 14.)
F-12
In January 2003, the FASB issued Interpretation No. 46, "Consolidation of
Variable Interest Entities" ("FIN 46"), which clarifies the application of
Accounting Research Bulletin No. 51, "Consolidated Financial Statements."
FIN 46 defines variable interest entities and how an enterprise should
assess its interests in a variable interest entity to decide whether to
consolidate that entity. The interpretation requires certain minimum
disclosures with respect to variable interest entities in which an
enterprise holds significant variable interest but which it does not
consolidate. FIN 46 applies immediately to variable interest entities
created after January 31, 2003, and to variable interest entities in which
an enterprise obtains an interest after that date. It applies in the first
fiscal year or interim period beginning after June 15, 2003 to variable
interest entities in which an enterprise holds a variable interest that it
acquired before February 1, 2003. FIN 46 applies to public enterprises as
of the beginning of the applicable interim or annual period, and it
applies to nonpublic enterprises as of the end of the applicable annual
period. FIN 46 may be applied prospectively with a cumulative-effect
adjustment as of the date on which it is first applied or by restating
previously issued financial statements for one or more years with a
cumulative-effect adjustment as of the beginning of the first year
restated. The Company has not determined the impact on its financial
position or results of operations that may result from the application of
FIN 46.
F-13
2. RECENT DEVELOPMENTS
CITGO's ultimate parent is PDVSA, the national oil company of the
Bolivarian Republic of Venezuela and its largest supplier of crude oil.
The Company has long-term crude oil supply agreements with PDVSA for a
portion of the crude oil requirements for the Company's Lake Charles,
Corpus Christi, Paulsboro and Savannah refineries.
A nation-wide work stoppage by opponents of President Hugo Chavez began in
Venezuela on December 2, 2002, and has disrupted most activity in that
country, including the operations of PDVSA. A significant number of
PDVSA's employees abandoned their jobs during the month of December. PDVSA
also informed the Company that its production of crude oil and natural
gas, as well as the export of crude oil and refined petroleum products,
were severely affected by these events in December. Subsequently, the
production and export of crude oil has been progressively increasing.
PDVSA has reported that some employees are returning to work.
The Company continues to be able to locate and purchase adequate crude
oil, albeit at higher prices than under the contracts with PDVSA, to
maintain normal operations at its refineries and to meet its refined
products commitments to its customers. In December 2002, the Company
received approximately 61 percent of the crude oil volumes that it
received from PDVSA in December 2001. In January 2003, the Company
received approximately 94 percent of the crude oil volumes that it
received from PDVSA in January 2002. Historically, the Company purchased
approximately 50 percent of its total crude oil requirements from PDVSA.
At December 31, 2002, the Company had approximately $90 million in
accounts payable related to crude oil deliveries from PDVSA for which
CITGO had not received invoices. The reduction in supply from PDVSA and
the purchase of crude oil from alternative sources has had the effect of
increasing CITGO's crude oil cost and decreasing its gross margin and
profit margin from what they would have been had the crude oil been
purchased under its long-term crude oil supply contracts with PDVSA.
The Company's liquidity has been adversely affected recently as a result
of events directly and indirectly associated with the disruption in its
Venezuelan crude oil supply from PDVSA. During this supply disruption, the
Company has been successful in covering any shortfall with spot market
purchases, but those purchases generally require payment fifteen days
sooner than would be the case for comparable deliveries under its supply
agreements with PDVSA. This shortening of the Company's payment cycle has
increased its cash needs and reduced its liquidity. Also, a number of
trade creditors have sought to tighten credit payment terms on purchases
that the Company makes from them. That tightening, if adopted by all
creditors, would increase the Company's cash needs and reduce its
liquidity.
In addition, all three major rating agencies lowered the Company's debt
ratings based upon, among other things, concerns regarding the supply
disruption. This downgrading caused a termination event under its existing
accounts receivable sale facility, which ultimately led to the repurchase
of $125 million in accounts receivable and cancellation of the facility on
January 31, 2003. That facility had a maximum size of $225 million of
which $125 million was used at the time of repurchase. The Company
received a letter of commitment from another lender on February 6, 2003 to
replace the cancelled facility. (See Note 6.)
Additionally, effective following the debt rating downgrade, the Company's
uncommitted, unsecured, short-term borrowing capacity is no longer
available.
Also, letter of credit providers for $76 million of the Company's
outstanding letters of credit have indicated that they will not renew such
letters of credit. These letters of credit support approximately
F-14
$75 million of tax-exempt bond issues that were issued previously for the
Company's benefit. The Company has an additional $231 million of letters
of credit outstanding that back or support other bond issues that it has
issued through governmental entities, which are subject to renewal during
2003. The Company has not received notice from the issuers of these
additional letters of credit indicating an intention not to renew. The
Company is working on replacing the letters of credit that will not be
renewed with letters of credit issued under its revolving credit
facilities. The Company is also considering arranging for the redemption
of certain tax-exempt bonds and the issuance of new tax-exempt bonds that
would not require letter of credit support.
Operating cash flow represents a primary source for meeting the Company's
liquidity requirements; however, the termination of its accounts
receivable sale facility, the possibility of additional tightened payment
terms and the possible need to replace non-renewing letters of credit has
prompted the Company to examine alternative arrangements to supplement and
improve its liquidity. CITGO management believes that the Company has
adequate liquidity from existing sources to support its operations for the
foreseeable future.
The Company is currently preparing a bond offering of approximately $550
million. However, the Company currently expects to use the net proceeds
for general corporate purposes. The Company may dividend up to $500
million of the net proceeds to PDV America to provide funds for the
repayment of PDV America's 7 7/8% Senior notes due August 1, 2003 if
permitted under the indenture governing the proposed notes to make such a
dividend.
3. REFINERY AGREEMENTS
An affiliate of PDVSA acquired a 50 percent equity interest in a refinery
in Chalmette, Louisiana ("Chalmette") in October 1997, and assigned to
CITGO its option to purchase up to 50 percent of the refined products
produced at the refinery through December 31, 2000 (Note 5). CITGO
exercised this option during 2000, and acquired approximately 67 MBPD of
refined products from the refinery, approximately one-half of which was
gasoline. The affiliate did not assign this option to CITGO for 2001 or
2002.
In October 1998, an affiliate of PDVSA acquired a 50 percent equity
interest in a joint venture that owns and operates a refinery in St.
Croix, U.S. Virgin Islands ("HOVENSA") and has the right under a product
sales agreement to assign periodically to CITGO, or other related parties,
its option to purchase 50 percent of the refined products produced by
HOVENSA (less a certain portion of such products that HOVENSA will market
directly in the local and Caribbean markets). In addition, under the
product sales agreement, the PDVSA affiliate has appointed CITGO as its
agent in designating which of its affiliates shall from time to time take
deliveries of the refined products available to it. The product sales
agreement will be in effect for the life of the joint venture, subject to
termination events based on default or mutual agreement (Note 5). Pursuant
to the above arrangement, CITGO acquired approximately 100 MBPD, 106 MBPD,
and 125 MBPD of refined products from HOVENSA during 2002, 2001, and 2000,
respectively, approximately one-half of which was gasoline.
4. INVESTMENT IN LYONDELL-CITGO REFINING LP
LYONDELL-CITGO Refining LP ("LYONDELL-CITGO") owns and operates a 265 MBPD
refinery in Houston, Texas and is owned by subsidiaries of CITGO (41.25%)
and Lyondell Chemical Company (58.75%) ("the Owners"). This refinery
processes heavy crude oil supplied by PDVSA under a long-term supply
contract that expires in 2017. CITGO purchases substantially all of the
gasoline, diesel and jet fuel produced at the refinery under a long-term
contract (Note 5).
F-15
At various times since April 1998, PDVSA, pursuant to its contractual
rights, declared force majeure and reduced deliveries of crude oil to
LYONDELL-CITGO; this required LYONDELL-CITGO to obtain alternative sources
of crude oil supply in replacement, which resulted in lower operating
margins. Most recently, LYONDELL-CITGO received notice of force majeure
from PDVSA in December 2002. Crude oil was purchased in the spot market to
replace the volume not delivered under the contract during December 2002.
By February 2003, crude oil deliveries had returned to contract volumes.
As of December 31, 2002, CITGO has outstanding loans to LYONDELL-CITGO of
$35 million. The notes bear interest at market rates, which were
approximately 2.4 percent, 2.2 percent, and 6.9 percent at December 31,
2002, 2001 and 2000. Principal and interest are due in December 2004.
Accordingly, these notes are included in other assets in the accompanying
consolidated balance sheets.
CITGO accounts for its investment in LYONDELL-CITGO using the equity
method of accounting and records its share of the net earnings of
LYONDELL-CITGO based on allocations of income agreed to by the Owners
which differs from participation interests. Cash distributions are
allocated to the Owners based on participation interest. Information on
CITGO's investment in LYONDELL-CITGO follows:
DECEMBER 31,
--------------------------------------
2002 2001 2000
(000'S OMITTED)
Carrying value of investment $ 518,279 $ 507,940 $ 518,333
Notes receivable 35,278 35,278 35,278
Participation interest 41% 41% 41%
Equity in net income $ 77,902 $ 73,983 $ 41,478
Cash distributions received 88,663 116,177 100,972
Summary of LYONDELL-CITGO's financial position:
Current assets $ 357,000 $ 227,000 $ 310,000
Noncurrent assets 1,400,000 1,434,000 1,386,000
Current liabilities:
Debt - 50,000 470,000
Distributions payable to partners 181,000 29,000 16,000
Other 333,000 298,000 381,000
Noncurrent liabilities (including debt of
$450,000 at December 31, 2002 and 2001
and $-0- at December 31, 2000) 840,000 776,000 321,000
Partners' capital 403,000 508,000 508,000
Summary of operating results:
Revenue $3,392,000 $3,284,000 $4,075,000
Gross profit 299,000 317,000 250,000
Net income 213,000 203,000 128,000
On December 11, 2002, LYONDELL-CITGO completed a refinancing of its
working capital revolver and its term bank loan. The new term loan and
working capital revolver will mature in June 2004.
F-16
5. RELATED PARTY TRANSACTIONS
The Company purchases approximately one-half of the crude oil processed in
its refineries from subsidiaries of PDVSA under long-term supply
agreements. These supply agreements extend through the year 2006 for the
Lake Charles refinery, 2010 for the Paulsboro refinery, 2012 for the
Corpus Christi refinery and 2013 for the Savannah refinery. The Company
purchased $3.3 billion, $3.0 billion, and $3.2 billion of crude oil,
feedstocks and other products from wholly owned subsidiaries of PDVSA in
2002, 2001, and 2000, respectively, under these and other purchase
agreements.
At various times since April 1998, PDVSA deliveries of crude oil to CITGO
were less than contractual base volumes due to PDVSA's declaration of
force majeure pursuant to all four long-term crude oil supply contracts
described above. Under a force majeure declaration, PDVSA may reduce the
amount of crude oil that it would otherwise be required to supply under
these agreements. When PDVSA reduces its delivery of crude oil under these
crude oil supply agreements, CITGO may obtain alternative sources of crude
oil which may result in increased crude costs or increase its purchases of
refined products. As a result, the Company was required to obtain
alternative sources of crude oil. See Note 2 for a description of events
that led to further disruptions of supplies in December 2002.
During 2002, 2001 and 2000, PDVSA did not deliver naphtha pursuant to
certain contracts and has made or will make contractually specified
payments in lieu thereof.
These crude oil supply agreements require PDVSA to supply minimum
quantities of crude oil and other feedstocks to CITGO for a fixed period.
The supply agreements differ somewhat for each refinery but generally
incorporate formula prices based on the market value of a slate of refined
products deemed to be produced from each particular grade of crude oil or
feedstock, less (i) specified deemed refining costs; (ii) specified actual
costs, including transportation charges, actual cost of natural gas and
electricity, import duties and taxes; and (iii) a deemed margin, which
varies according to the grade of crude oil or feedstock delivered. Under
each supply agreement, deemed margins and deemed costs are adjusted
periodically by a formula primarily based on the rate of inflation.
Because deemed operating costs and the slate of refined products deemed to
be produced for a given barrel of crude oil or other feedstock do not
necessarily reflect the actual costs and yields in any period, the actual
refining margin earned by CITGO under the various supply agreements will
vary depending on, among other things, the efficiency with which CITGO
conducts its operations during such period. At December 31, 2002 and 2001,
$262 million and $185 million, respectively, were included in payables to
affiliates as a result of these transactions. At December 31, 2002, the
Company had approximately $90 million in accounts payable related to crude
oil deliveries from PDVSA for which CITGO had not received invoices.
The price CITGO pays for crude oil purchased under these crude oil supply
agreements is not directly related to the market price of any other crude
oil. However, the intention of the pricing mechanism in the crude supply
agreements was to reflect market pricing over long periods of time, but
there may be periods in which the price paid for crude oil purchased under
those agreements may be higher or lower than the price that might have
been paid in the spot market. Internal estimates indicate that the pricing
mechanism is working as intended to reflect market prices over long
periods of time.
The Company also purchases refined products from various other affiliates
including LYONDELL-CITGO, HOVENSA and Chalmette, under long-term
contracts. These agreements incorporate various formula prices based on
published market prices and other factors. Such purchases totaled $3.5
billion, $3.4 billion, and $5.3 billion for 2002, 2001, and 2000,
respectively. At December 31, 2002 and 2001, $110 million and $73 million,
respectively, were included in payables to affiliates as a result of these
transactions.
F-17
The Company had refined product, feedstock, and other product sales to
affiliates, primarily at market-related prices, of $277 million, $248
million, and $205 million in 2002, 2001, and 2000, respectively. At
December 31, 2002 and 2001, $94 million and $64 million, respectively, was
included in due from affiliates as a result of these and related
transactions.
Under a separate guarantee of rent agreement, PDVSA has guaranteed payment
of rent, stipulated loss value and terminating value due under the lease
of the Corpus Christi refinery facilities described in Note 15. The
Company has also guaranteed debt of certain affiliates (Note 14).
In August 2002, three affiliates entered into agreements to advance excess
cash to CITGO from time to time under demand notes for amounts of up to a
maximum of $10 million with PDV Texas, Inc. ("PDV Texas"), $30 million
with PDV America and $10 million with PDV Holding, Inc. ("PDV Holding").
The notes bear interest at rates equivalent to 30-day LIBOR plus .875%
payable quarterly. Amounts outstanding on these notes at December 31, 2002
were $5 million, $30 million and $4 million from PDV Texas, PDV America
and PDV Holding, respectively and are included in payables to affiliates
in the accompanying consolidated balance sheet.
The Company and PDV Holding are parties to a tax allocation agreement that
is designed to provide PDV Holding with sufficient cash to pay its
consolidated income tax liabilities. PDV Holding appointed CITGO as its
agent to handle the payment of such liabilities on its behalf. As such,
CITGO calculates the taxes due, allocates the payments among the members
according to the agreement and bills each member accordingly. Each member
records its amounts due or payable to CITGO in a related party payable
account. At December 31, 2002 and 2001, CITGO had net related party
receivables related to federal income taxes of $25 million and $23
million, respectively.
Prior to the formation of PDV Holding as the common parent in the 1997 tax
year, the Company and PDV America were parties to a tax allocation
agreement. In 1998, $8 million due from CITGO to PDV America under this
agreement for the 1997 tax year was classified as a noncash contribution
of capital. In 1999, $11 million due from PDV America to CITGO under this
agreement for the 1998 tax year was classified as a noncash dividend.
Amendment No. 2 to the Tax Allocation Agreement was executed during 2000;
this amendment eliminated the provisions of the agreement that provided
for these noncash contribution and dividend classifications effective with
the 1997 tax year. Consequently, the classifications made in the prior two
years were reversed in 2000. In the event that CITGO should cease to be
part of the consolidated federal income tax group, any amounts included in
shareholder's equity under this agreement are required to be settled
between the parties in cash (net $2 million payable to PDV America at
December 31, 2002 and 2001).
At December 31, 2002, CITGO has federal income taxes payable of $20
million included in other current liabilities. At December 31, 2001, CITGO
had income tax prepayments of $76 million included in prepaid expenses.
F-18
6. ACCOUNTS RECEIVABLE
2002 2001
(000's OMITTED)
Trade $ 766,824 $ 718,319
Credit card 116,246 121,334
Other 39,313 87,195
--------- ---------
922,383 926,848
Allowance for uncollectible accounts (17,205) (13,780)
--------- ---------
$ 905,178 $ 913,068
========= =========
Sales are made on account, based on pre-approved unsecured credit terms
established by CITGO management. The Company also has a proprietary
credit card program which allows commercial customers to purchase fuel
at CITGO branded outlets. Allowances for uncollectible accounts are
established based on several factors that include, but are not limited
to, analysis of specific customers, historical trends, current economic
conditions and other information.
The Company has a limited purpose consolidated subsidiary, CITGO
Funding Corporation, which established a non-recourse agreement to sell
an undivided interest in specified trade accounts receivables ("pool")
to independent third parties. Under the terms of the agreement, new
receivables are added to the pool as collections (administered by
CITGO) reduce previously sold receivables. CITGO pays specified fees
related to its sale of receivables under the program. The amount sold
at any one time under the trade accounts receivable sales agreement was
limited to a maximum of $225 million (increased from $125 million
through an amendment in April 2000).
As of December 31, 2002 and 2001, $765 million and $640 million,
respectively, of CITGO's accounts receivable comprised the designated
pool of trade receivables included in this program. These receivables
had weighted average lives of 5.0 and 4.5 days and included no
delinquent accounts under 61 days overdue at December 31, 2002 and
2001. Of the receivables in the designated pool, $125 million was sold
to the third party and the remaining amount was retained by CITGO
Funding as of December 31, 2002 and 2001. This retained interest, which
is included in receivables, net in the consolidated balance sheets, is
recorded at fair value. Due to (i) a short average collection cycle for
such trade receivables, (ii) CITGO's positive collection history, and
(iii) the characteristics of such trade accounts receivables, the fair
value of CITGO's retained interest approximates the total amount of
trade accounts receivable reduced by the amount of trade accounts
receivable sold to the third-party under the facility. CITGO recorded
no gains or losses associated with the sales in the years ended
December 31, 2002 and 2001.
CITGO is responsible for servicing the transferred receivables. It does
not receive any fees for this servicing activity, and it does not
believe that it incurs incremental costs associated with the activity.
As a result, it has not recorded any servicing assets or liabilities
related to this servicing activity.
The fees incurred by CITGO related to this facility, which were
included in other income (expense), net in the consolidated statements
of income, were $3.3 million, $7.6 million and $16 million for the
years ended December 31, 2002, 2001 and 2000, respectively. The third
party's interests in CITGO trade accounts receivables were never in
excess of the sales facility limits at any time under this program. No
accounts receivable included in this program were written off as
uncollectible during 2002, 2001 or 2000.
F-19
In January 2003, CITGO's debt rating was lowered based upon, among
other things, concerns regarding the supply disruption of crude oil
from Venezuela. This downgrade caused a termination event under the
trade accounts receivable sales agreement, which ultimately led to the
cancellation of the facility and the voluntary repurchase of $125
million in accounts receivable on January 31, 2003.
On February 6, 2003, the Company received a letter of commitment from
another lender to replace the cancelled facility. Under the terms of
the proposed agreement, new receivables will be added to the pool as
collections (administered by CITGO) reduce previously sold receivables.
The amount sold at any one time will be limited to a maximum of $200
million.
In 2000, the Company realized a gain of $5 million resulting from the
reversal of the allowance for uncollectible accounts related to certain
receivables sold.
7. INVENTORIES
2002 2001
(000's OMITTED)
Refined product $ 781,495 $ 836,683
Crude oil 221,422 193,319
Materials and supplies 87,998 79,344
---------- ----------
$1,090,915 $1,109,346
========== ==========
At December 31, 2002 and 2001, estimated net market values exceeded
historical cost by approximately $572 million and $174 million,
respectively.
The reduction of hydrocarbon LIFO inventory quantities resulted in a
liquidation of prior years' LIFO layers and decreased cost of goods
sold by $29 million in 2002.
8. PROPERTY, PLANT AND EQUIPMENT
2002 2001
(000's OMITTED)
Land $ 138,156 $ 137,927
Buildings and leaseholds 431,899 470,465
Machinery and equipment 4,532,889 3,951,191
Vehicles 24,597 23,866
Construction in process 384,869 219,938
----------- -----------
5,512,410 4,803,387
Accumulated depreciation and amortization (1,762,244) (1,510,918)
----------- -----------
$ 3,750,166 $ 3,292,469
=========== ===========
Depreciation expense for 2002, 2001, and 2000 was $223 million, $220
million, and $222 million, respectively.
Other income (expense) includes gains and losses on disposals and
retirements of property, plant and equipment. Such net losses were
approximately $5 million, $24 million, and $11 million in 2002, 2001,
and 2000, respectively.
F-20
9. INVESTMENTS IN AFFILIATES
In addition to LYONDELL-CITGO, the Company's investments in affiliates
consist of equity interests of 6.8 percent to 50 percent in joint
interest pipelines and terminals, including a 15.79 percent interest in
Colonial Pipeline Company; a 49.5 percent partnership interest in
Nelson Industrial Steam Company ("NISCO"), which is a qualified
cogeneration facility; a 49 percent partnership interest in Mount
Vernon Phenol Plant; and a 25 percent interest in The Needle Coker
Company. The carrying value of these investments exceeded the Company's
equity in the underlying net assets by approximately $137.6 million and
$139 million at December 31, 2002 and 2001, respectively.
At December 31, 2002 and 2001, NISCO had a partnership deficit. CITGO's
share of this deficit, as a general partner, was $34.0 million and
$39.5 million at December 31, 2002 and 2001, respectively, which is
included in other noncurrent liabilities in the accompanying
consolidated balance sheets.
Information on the Company's investments, including LYONDELL-CITGO,
follows:
DECEMBER 31,
----------------------------------
2002 2001 2000
(000's OMITTED)
Company's investments in affiliates
(excluding NISCO) $716,469 $700,701 $712,560
Company's equity in net income of affiliates 101,326 108,915 58,728
Dividends and distributions received from affiliates 123,639 153,435 126,600
Selected financial information provided by the affiliates is summarized
as follows:
DECEMBER 31,
----------------------------------------
2002 2001 2000
(000's OMITTED)
Summary of financial position:
Current assets $ 740,019 $ 566,204 $ 638,297
Noncurrent assets 3,396,209 3,288,950 3,005,582
Current liabilities (including debt of $52,417,
$685,089 and $729,806 at December 31,
2002, 2001, and 2000, respectively) 846,623 1,240,391 1,336,989
Noncurrent liabilities (including debt of
$2,185,502, $1,460,196 and $1,274,069
at December 31, 2002, 2001, and 2000,
respectively) 2,863,505 2,082,573 1,874,465
Summary of operating results:
Revenues $4,906,397 $4,603,136 $5,221,382
Gross profit 879,907 781,630 700,317
Net income 449,779 397,501 325,489
10. SHORT-TERM BANK LOANS
As of December 31, 2002, the Company has established $90 million of
uncommitted, unsecured, short-term borrowing facilities with various
banks. Interest rates on these facilities are determined daily based
upon the federal funds' interest rates, and maturity options vary up to
30 days. The weighted
F-21
average interest rates actually incurred in 2002, 2001, and 2000 were
2.5 percent, 2.3 percent, and 6.4 percent, respectively. The Company
had no borrowings outstanding under these facilities at December 31,
2002 and 2001.
As of January 13, 2003, following a debt rating downgrade, this
uncommitted, unsecured, short-term borrowing capacity is no longer
available.
11. LONG-TERM DEBT AND FINANCING ARRANGEMENTS
2002 2001
(000's OMITTED)
Revolving bank loans $ 279,300 $ 391,500
Senior Notes $200 million face amount, due 2006 with
interest rate of 7.875% 199,898 199,867
Private Placement Senior Notes, due 2003 to 2006 with an
interest rate of 9.30% 45,455 56,819
Master Shelf Agreement Senior Notes, due 2003 to
2009 with interest rates from 7.17% to 8.94% 235,000 260,000
Tax-Exempt Bonds, due 2004 to 2032 with variable
and fixed interest rates 425,872 357,370
Taxable Bonds, due 2026 to 2028 with variable interest rates 115,000 146,000
----------- -----------
1,300,525 1,411,556
Current portion of long-term debt (190,664) (107,864)
----------- -----------
$ 1,109,861 $ 1,303,692
=========== ===========
REVOLVING BANK LOANS - The Company's credit agreements with various
banks consist of (i) a $260 million, three-year, revolving bank loan
maturing in December 2005; (ii) a $260 million, 364-day, revolving bank
loan maturing in December 2003; and (iii) a $25 million, 364-day,
revolving bank loan maturing in May 2003, all of which are unsecured
and have various interest rate options. Interest rates on the revolving
bank loans ranged from 2.4 percent to 2.5 percent at December 31, 2002;
$279 million was outstanding under these credit agreements at December
31, 2002.
SHELF REGISTRATION - SENIOR NOTES - In April 1996, the Company filed a
registration statement with the Securities and Exchange Commission
relating to the shelf registration of $600 million of debt securities
that may be offered and sold from time to time. In May 1996, the
registration became effective and CITGO sold a tranche of debt
securities with an aggregate offering price of $200 million. On October
28, 1997, the Company entered into a Selling Agency Agreement with
Salomon Brothers Inc. and Chase Securities Inc. providing for the sale
of up to an additional $235 million in aggregate principal amount of
notes in tranches from time to time by the Company under the shelf
registration. No amounts were sold under this agreement as of December
31, 2002. Due to downgradings of CITGO's credit ratings announced
during the first part of 2003, the shelf registration statement is not
presently available. (See Note 2.)
F-22
PRIVATE PLACEMENT - At December 31, 2002, the Company has outstanding
approximately $45 million of privately placed, unsecured Senior Notes.
Principal amounts are payable in annual installments in November and
interest is payable semiannually in May and November.
MASTER SHELF AGREEMENT - At December 31, 2002, the Company has
outstanding $235 million of privately-placed senior notes under an
unsecured Master Shelf Agreement with an insurance company. The notes
have various fixed interest rates and maturities.
COVENANTS - The various debt agreements above contain certain covenants
that, depending upon the level of the Company's capitalization and
earnings, could impose limitations on the Company's ability to pay
dividends, incur additional debt, place liens on property, and sell
fixed assets. The Company's debt instruments described above do not
contain any covenants that trigger prepayment or increased costs as a
result of a change in its debt ratings. The Company was in compliance
with the debt covenants at December 31, 2002.
TAX-EXEMPT BONDS - At December 31, 2002, through state entities, CITGO
has outstanding $49.8 million of industrial development bonds for
certain Lake Charles port facilities and pollution control equipment
and $356.2 million of environmental revenue bonds to finance a portion
of the Company's environmental facilities at its Lake Charles and
Corpus Christi refineries and at the LYONDELL-CITGO refinery. The bonds
bear interest at various fixed and floating rates, which ranged from
2.1 percent to 8.0 percent at December 31, 2002 and ranged from 2.5
percent to 6.0 percent at December 31, 2001. Additional credit support
for the variable rate bonds is provided through letters of credit.
PDVMR has issued $19.9 million of variable rate pollution control
bonds, with interest currently paid monthly. The bonds have one payment
at maturity in the year 2008 to retire the principal, and principal and
interest payments are guaranteed by a $20.3 million letter of credit.
TAXABLE BONDS - At December 31, 2002, through state entities, the
Company has outstanding $115 million of taxable environmental revenue
bonds to finance a portion of the Company's environmental facilities at
its Lake Charles refinery and at the LYONDELL-CITGO refinery. Such
bonds are secured by letters of credit and have floating interest rates
(2.5 percent at December 31, 2002 and 3.1 percent at December 31,
2001). At the option of the Company and upon the occurrence of certain
specified conditions, all or any portion of such taxable bonds may be
converted to tax-exempt bonds. During 2002, 2001 and 2000, $31 million,
$28 million and $0 of originally issued taxable bonds were converted to
tax-exempt bonds.
DEBT MATURITIES - Future maturities of long-term debt as of December
31, 2002, are: 2003 - $190.7 million, 2004 - $47.2 million, 2005 -
$161.3 million, 2006 - $251.2 million, 2007 - $61.8 million and $588.3
million thereafter.
F-23
INTEREST RATE SWAP AGREEMENTS - The Company has entered into the
following interest rate swap agreements to reduce the impact of
interest rate changes on its variable interest rate debt:
NOTIONAL PRINCIPAL AMOUNT
-------------------------
EXPIRATION FIXED RATE 2002 2001
VARIABLE RATE INDEX DATE PAID (000's OMITTED)
J.J. Kenny February 2005 5.30% $12,000 $12,000
J.J. Kenny February 2006 5.27% 15,000 15,000
J.J. Kenny February 2007 5.49% 15,000 15,000
------- -------
$42,000 $42,000
======= =======
Interest expense includes $0.6 million in 2000 related to the net
settlements on these agreements. Effective January 1, 2001, changes in
the fair value of these agreements are recorded in other income
(expense). The fair value of these agreements at December 31, 2002,
based on the estimated amount that CITGO would receive or pay to
terminate the agreements as of that date and taking into account
current interest rates, was a loss of $3.5 million, the offset of which
is recorded in the balance sheet caption other current liabilities.
12. EMPLOYEE BENEFIT PLANS
EMPLOYEE SAVINGS - CITGO sponsors three qualified defined contribution
retirement and savings plans covering substantially all eligible
salaried and hourly employees. Participants make voluntary
contributions to the plans and CITGO makes contributions, including
matching of employee contributions, based on plan provisions. CITGO
expensed $23 million, $20 million and $17 million related to its
contributions to these plans in 2002, 2001 and 2000, respectively.
PENSION BENEFITS - CITGO sponsors three qualified noncontributory
defined benefit pension plans, two covering eligible hourly employees
and one covering eligible salaried employees. CITGO also sponsors three
nonqualified defined benefit plans for certain eligible employees. The
qualified plans' assets include corporate securities, shares in a fixed
income mutual fund, two collective funds and a short-term investment
fund. The nonqualified plans are not funded.
CITGO's policy is to fund the qualified pension plans in accordance
with applicable laws and regulations and not to exceed the tax
deductible limits. The nonqualified plans are funded as necessary to
pay retiree benefits. The plan benefits for each of the qualified
pension plans are primarily based on an employee's years of plan
service and compensation as defined by each plan.
POSTRETIREMENT BENEFITS OTHER THAN PENSIONS - In addition to pension
benefits, CITGO also provides certain health care and life insurance
benefits for eligible salaried and hourly employees at retirement.
These benefits are subject to deductibles, copayment provisions and
other limitations and are primarily funded on a pay-as-you-go basis.
CITGO reserves the right to change or to terminate the benefits at any
time.
F-24
The following sets forth the changes in benefit obligations and plan
assets for the CITGO pension and postretirement plans for the years
ended December 31, 2002 and 2001, and the funded status of such plans
reconciled with amounts reported in the Company's consolidated balance
sheets:
PENSION BENEFITS OTHER BENEFITS
---------------------- ------------------------
2002 2001 2002 2001
(000s OMITTED) (000s OMITTED)
CHANGE IN BENEFIT OBLIGATION:
Benefit obligation at beginning of year $336,917 $288,188 $ 260,696 $ 206,276
Service cost 17,171 15,680 7,191 5,754
Interest cost 24,007 21,798 18,603 15,708
Plan vesting changes 30 - - -
Actuarial loss 27,371 23,130 55,654 40,556
Benefits paid (11,670) (11,879) (7,993) (7,598)
-------- -------- --------- ---------
Benefit obligation at end of year 393,826 336,917 334,151 260,696
-------- -------- --------- ---------
CHANGE IN PLAN ASSETS:
Fair value of plan assets at beginning of year 263,953 272,889 1,115 1,053
Actual return on plan assets (20,666) (10,185) 67 62
Employer contribution 9,182 13,128 7,993 7,598
Benefits paid (11,670) (11,879) (7,993) (7,598)
-------- -------- --------- ---------
Fair value of plan assets at end of year 240,799 263,953 1,182 1,115
-------- -------- --------- ---------
Funded status (153,027) (72,965) (332,969) (259,581)
Unrecognized net actuarial loss (gain) 69,184 (1,991) 75,206 30,840
Unrecognized prior service cost 1,972 2,293 - -
Net gain at date of adoption (207) (475) - -
-------- -------- --------- ---------
Net amount recognized $(82,078) $(73,138) $(257,763) $(228,741)
======== ======== ========= =========
Amounts recognized in the Company's consolidated balance sheets consist of:
Accrued benefit liability $(91,093) $(80,238) $(257,763) $(228,741)
Intangible asset 2,308 3,035 - -
Accumulated other comprehensive income 6,707 4,065 - -
-------- -------- --------- ---------
Net amount recognized $(82,078) $(73,138) $(257,763) $(228,741)
======== ======== ========= =========
PENSION BENEFITS OTHER BENEFITS
--------------------- ------------------------
2002 2001 2002 2001
WEIGHTED-AVERAGE ASSUMPTIONS AS OF
DECEMBER 31:
Discount rate 6.75 % 7.25 % 6.75 % 7.25 %
Expected return on plan assets 8.50 % 9.00 % 6.00 % 6.00 %
Rate of compensation increase 5.00 % 5.00 % - -
F-25
For measurement purposes, a 10 percent pre-65 and an 11 percent post-65
annual rate of increase in the per capita cost of covered health care
benefits was assumed for 2002. These rates are assumed to decrease 1
percent per year to an ultimate level of 5 percent by 2008 for pre-65
and 2009 for post-65 participants, and to remain at that level
thereafter.
PENSION BENEFITS OTHER BENEFITS
---------------------------------- ------------------------------
2002 2001 2000 2002 2001 2000
(000s OMITTED) (000s OMITTED)
Components of net periodic benefit cost:
Service cost $ 17,171 $ 15,680 $ 15,533 $ 7,191 $ 5,754 $ 5,769
Interest cost 24,007 21,798 19,680 18,603 15,708 14,392
Expected return on plan assets (23,668) (24,165) (24,397) (67) (63) (59)
Amortization of prior service 350 351 143 - - -
Amortization of net gain at
date of adoption (268) (268) (268) - - -
Recognized net actuarial gain 530 (3,021) (4,824) 11,288 - (17,254)
-------- -------- --------- ------- ------- --------
Net periodic benefit cost $ 18,122 $ 10,375 $ 5,867 $37,015 $21,399 $ 2,848
======== ======== ========= ======= ======= ========
One-time adjustment $ - $ - $ 2,875 $ - $ - $ -
======== ======== ========= ======= ======= ========
Actuarial gains (or losses) related to the postretirement benefit
obligation are recognized as a component of net postretirement benefit
cost by the amount the beginning of year unrecognized net gain (or
loss) exceeds 7.5 percent of the accumulated postretirement benefit
obligation.
The projected benefit obligation, accumulated benefit obligation, and
fair value of plan assets for the pension plan with accumulated benefit
obligations in excess of plan assets were $37.3 million, $32.7 million
and $0, respectively, as of December 31, 2002, and $33.4 million, $29.3
million and $0, respectively, as of December 31, 2001.
Assumed health care cost trend rates have a significant effect on the
amounts reported for the health care plans. A one-percentage-point
change in assumed health care cost trend rates would have the following
effects:
1-PERCENTAGE- 1-PERCENTAGE-
POINT INCREASE POINT DECREASE
-------------- --------------
(000's OMITTED)
Increase (decrease) in total of service and interest cost
components $ 4,623 $ (3,679)
Increase (decrease) in postretirement benefit obligation 52,653 (42,496)
PDVMR PENSION PLANS - In connection with the creation of PDVMR, on May
1, 1997, PDVMR assumed the responsibility for a former partnership's
pension plans, which include both a qualified and a nonqualified plan
which were frozen at their current levels on April 30, 1997. The plans
cover former employees of the partnership who were participants in the
plans as of April 30, 1997. At December 31, 2002 and 2001, plan assets
consisted of equity securities, bonds and cash.
The following sets forth the changes in benefit obligations and plan
assets for the PDVMR pension plans for the years ended December 31,
2002 and 2001, and the funded status of such plans reconciled with
amounts reported in the Company's consolidated balance sheets:
F-26
2002 2001
-------- --------
(000s OMITTED)
Change in benefit obligation:
Benefit obligation at beginning of year $ 53,590 $ 51,446
Interest cost 3,873 3,934
Actuarial loss (gain) 1,079 (2)
Benefits paid (2,713) (1,788)
-------- --------
Benefit obligation at end of year 55,829 53,590
-------- --------
Change in plan assets:
Fair value of plan assets at beginning of year 60,288 66,737
Actual return on plan assets (7,886) (4,661)
Employer contribution 106 -
Benefits paid (2,713) (1,788)
-------- --------
Fair value of plan assets at end of year 49,795 60,288
-------- --------
Funded status (6,033) 6,698
Unrecognized net actuarial loss 21,676 6,091
-------- --------
Net amount recognized $ 15,643 $ 12,789
======== ========
Amounts recognized in the Company's
consolidated balance sheets consist of:
Prepaid Pension Cost - 13,179
Accrued benefit liability (6,033) (487)
Accumulated other comprehensive income 21,676 97
-------- --------
Net amount recognized $ 15,643 $ 12,789
======== ========
2002 2001
------ ------
WEIGHTED-AVERAGE ASSUMPTIONS AS OF DECEMBER 31:
Discount rate 6.75% 7.25%
Expected return on plan assets 8.50% 9.50%
2002 2001 2000
------- ------- -------
COMPONENTS OF NET PERIODIC BENEFIT CREDIT:
Interest cost $ 3,873 $ 3,934 $ 3,823
Expected return on plan assets (6,625) (6,421) (6,123)
Recognized net actuarial loss (gain) 4 3 (55)
------- ------- -------
Net periodic benefit credit $(2,748) $(2,484) $(2,355)
======= ======= =======
The projected benefit obligation of the nonqualified plan (which equals
the accumulated benefit obligation for this plan) was $380,000 as of
December 31, 2002 and $487,000 as of December 31, 2001. The plan is
unfunded.
F-27
13. INCOME TAXES
The provisions for income taxes are comprised of the following:
2002 2001 2000
(000's OMITTED)
Current:
Federal $ 47,087 $ 84,960 $125,068
State 751 5,686 4,614
Foreign 222 - -
-------- -------- --------
48,060 90,646 129,682
Deferred 47,813 115,576 52,945
-------- -------- --------
$ 95,873 $206,222 $182,627
======== ======== ========
The federal statutory tax rate differs from the effective tax rate due
to the following:
2002 2001 2000
Federal statutory tax rate 35.0 % 35.0 % 35.0 %
State taxes, net of federal benefit 2.4 % 0.9 % 1.6 %
Dividend exclusions (3.0)% (1.2)% (1.3)%
Other 0.4 % (0.2)% 1.6 %
---- ---- ----
Effective tax rate 34.8 % 34.5 % 36.9 %
==== ==== ====
F-28
Deferred income taxes reflect the net tax effects of (i) temporary
differences between the financial and tax bases of assets and
liabilities, and (ii) loss and tax credit carryforwards. The tax
effects of significant items comprising the Company's net deferred tax
liability as of December 31, 2002 and 2001 are as follows:
2002 2001
(000'S OMITTED)
Deferred tax liabilities:
Property, plant and equipment $ 754,990 $ 710,131
Inventories 81,912 93,459
Investments in affiliates 173,603 173,724
Other 95,886 58,170
---------- ----------
1,106,391 1,035,484
---------- ----------
Deferred tax assets:
Postretirement benefit obligations 99,234 88,049
Employee benefit accruals 58,002 57,243
Alternative minimum tax credit carryforwards 64,687 59,929
Net operating loss carryforwards 25,997 1,602
Marketing and promotional accruals 4,815 4,989
Other 48,275 51,970
---------- ----------
301,010 263,782
---------- ----------
Net deferred tax liability (of which $29,499 is included in current
assets at December 31, 2002 and $4,365 is included in current
liabilities at December 31, 2001.) $ 805,381 $ 771,702
========== ==========
The Company's alternative minimum tax credit carryforwards are
available to offset regular federal income taxes in future years
without expiration, subject to certain alternative minimum tax
limitations.
14. COMMITMENTS AND CONTINGENCIES
LITIGATION AND INJURY CLAIMS - Various lawsuits and claims arising in
the ordinary course of business are pending against the Company. The
Company records accruals for potential losses when, in management's
opinion, such losses are probable and reasonably estimable. If known
lawsuits and claims were to be determined in a manner adverse to the
Company, and in amounts greater than the Company's accruals, then such
determinations could have a material adverse effect on the Company's
results of operations in a given reporting period. The most significant
lawsuits and claims are discussed below.
A class action lawsuit brought by four former marketers of the UNO-VEN
Company ("UNO-VEN") in U.S. District Court in Wisconsin against UNO-VEN
alleging improper termination of the UNO-VEN Marketer Sales Agreement
under the Petroleum Marketing Practices Act in connection with PDVMR's
1997 acquisition of Unocal's interest in UNO-VEN has resulted in the
judge granting the Company's motion for summary judgment. The
plaintiffs appealed the summary judgment and the Seventh Circuit of the
U.S. Court of Appeals has affirmed the judgment. The time for an appeal
to the U.S. Supreme court has expired, and therefore, this action is
concluded.
The Company has settled a lawsuit against PDVMR and CITGO in Illinois
state court which claimed damages as a result of PDVMR invoicing a
partnership in which it is a partner, and an affiliate of the other
partner of the partnership, allegedly excessive charges for electricity
by these entities' facilities located adjacent to the Lemont, Illinois
refinery. The electricity supplier to the refinery is seeking
F-29
recovery from the Company of alleged underpayments for electricity. The
Company has denied all allegations and is pursuing its defenses.
In May 1997, a fire occurred at CITGO's Corpus Christi refinery.
Approximately seventeen related lawsuits were filed in federal and
state courts in Corpus Christi, Texas against CITGO on behalf of
approximately 9,000 individuals alleging property damages, personal
injury and punitive damages. In September 2002, CITGO reached an
agreement to settle substantially all of the claims related to this
incident for an amount that did not have a material financial impact on
the Company.
In September 2002, a state District Court in Corpus Christi, Texas has
ordered CITGO to pay property owners and their attorneys approximately
$6 million based on alleged settlement of class action property damage
claims as a result of alleged air, soil and groundwater contamination
from emissions released from CITGO's Corpus Christi, Texas refinery.
CITGO has appealed the ruling to Texas Court of Appeals.
Litigation is pending in federal court in Lake Charles, Louisiana
against CITGO by a number of current and former refinery employees and
applicants asserting claims of racial discrimination in connection with
CITGO's employment practices. A trial involving two plaintiffs resulted
in verdicts for the Company. The Court granted the Company summary
judgment with respect to another group of plaintiffs' claims, which
rulings were appealed and affirmed by the Fifth Circuit Court of
Appeals. Trials of the remaining cases are set to begin in December
2003. The Company does not expect that the ultimate resolution of these
cases will have an adverse material effect on its financial condition
or results of operations.
CITGO is among refinery defendants to state and federal lawsuits in New
York and state actions in Illinois and California alleging
contamination of water supplies by methyl tertiary butyl ether
("MTBE"), a component of gasoline. Plaintiffs claim that MTBE is a
defective product and that refiners failed to adequately warn customers
and the public about risks associated with the use of MTBE in gasoline.
These actions allege that MTBE poses public health risks and seek
testing, damages and remediation of the alleged contamination.
Plaintiffs filed putative class action lawsuits in federal courts in
Illinois, California, Florida and New York. CITGO was named as a
defendant in all but the California case. The federal cases were all
consolidated in a Multidistrict Litigation case in the United States
District Court for the Southern District of New York ("MDL 1358"). In
July 2002, the court in the MDL case denied plaintiffs' motion for
class certification. The Company does not expect that the resolution of
the MDL and California lawsuits will have a material impact on CITGO's
financial condition or results of operations. In August 2002, a New
York state court judge handling two separate but related individual
MTBE lawsuits dismissed plaintiffs' product liability claims, leaving
only traditional nuisance and trespass claims for leakage from
underground storage tanks at gasoline stations near plaintiffs' water
wells. Subsequently, a putative class action involving the same leaking
underground storage tanks has been filed. CITGO anticipates filing a
motion to dismiss the product liability claims and will also oppose
class certification. Also, in late October 2002, The County of Suffolk,
New York, and the Suffolk County Water Authority filed suit in state
court, claiming MTBE contamination of that county's water supply. The
judge in the Illinois state court action is expected to hear
plaintiffs' motion for class certification in that case sometime within
the next year.
In August 1999, the U.S. Department of Commerce rejected a petition
filed by a group of independent oil producers to apply antidumping
measures and countervailing duties against imports of crude oil from
Venezuela, Iraq, Mexico and Saudi Arabia. The petitioners appealed this
decision before the U.S. Court of International Trade based in New
York, where the matter is still pending. On September 19, 2000, the
Court of International Trade remanded the case to the Department of
Commerce with instructions to reconsider its August 1999 decision. The
Department of Commerce was required to make a revised
F-30
decision as to whether or not to initiate an investigation within 60
days. The Department of Commerce appealed to the U.S. Court of Appeals
for the Federal Circuit, which dismissed the appeal as premature on
July 31, 2001. The Department of Commerce issued its revised decision,
which again rejected the petition, in August 2001. The revised decision
was affirmed by the Court of International Trade at December 17, 2002.
The independent oil producers may or may not appeal the Court of
International Trade's decision.
Approximately 140 lawsuits are currently pending against the Company in
state and federal courts, primarily in Louisiana and Texas. The cases
were brought by former employees and contractor employees seeking
damages for asbestos related illnesses allegedly resulting from
exposure at refineries owned or operated by the Company in Lake
Charles, Louisiana and Corpus Christi, Texas. In many of these cases,
there are multiple defendants. In some cases, the Company is
indemnified by or has the right to seek indemnification for losses and
expense that it may incur from prior owners of the refineries or
employers of the claimants. The Company does not believe that the
resolution of the cases will have an adverse material effect on its
financial condition or results of operations.
ENVIRONMENTAL COMPLIANCE AND REMEDIATION - The U.S. refining industry
is required to comply with increasingly stringent product
specifications under the 1990 Clean Air Act Amendments for reformulated
gasoline and low sulphur gasoline and diesel fuel that have
necessitated additional capital and operating expenditures. Also,
regulatory interpretations by the U.S. EPA regarding "modifications" to
refinery equipment under the New Source Review ("NSR"), provisions of
the Clean Air Act have created uncertainty about the extent to which
additional capital and operating expenditures will be required and
administrative penalties imposed. In addition to the Clean Air Act,
CITGO is subject to various other federal, state and local
environmental laws and regulations which may require CITGO to take
additional compliance actions and also actions to remediate the effects
on the environment of prior disposal or release of petroleum, hazardous
substances and other waste and/or pay for natural resource damages.
Maintaining compliance with environmental laws and regulations could
require significant capital expenditures and additional operating
costs. Also, numerous other factors affect the Company's plans with
respect to environmental compliance and related expenditures.
CITGO's accounting policy establishes environmental reserves as
probable site restoration and remediation obligations become reasonably
capable of estimation. CITGO believes the amounts provided in its
consolidated financial statements, as prescribed by generally accepted
accounting principles, are adequate in light of probable and estimable
liabilities and obligations. However, there can be no assurance that
the actual amounts required to discharge alleged liabilities and
obligations and to comply with applicable laws and regulations will not
exceed amounts provided for or will not have a material adverse affect
on its consolidated results of operations, financial condition and cash
flows.
In 1992, the Company reached an agreement with the Louisiana Department
of Environmental Quality ("LDEQ") to cease usage of certain surface
impoundments at the Lake Charles refinery by 1994. A mutually
acceptable closure plan was filed with the LDEQ in 1993. The Company
and its former owner are participating in the closure and sharing the
related costs based on estimated contributions of waste and ownership
periods. The remediation commenced in December 1993. In 1997, the
Company presented a proposal to the LDEQ revising the 1993 closure
plan. In 1998 and 2000, the Company submitted further revisions as
requested by the LDEQ. The LDEQ issued an administrative order in June
2002 that addressed the requirements and schedule for proceeding to
develop and implement the corrective action or closure plan for these
surface impoundments and related waste units. Compliance with the terms
of the administrative order has begun.
The Texas Commission on Environmental Quality ("TCEQ") conducted a
multi-media investigation of the Corpus Christi Refinery during the
second quarter of 2002 and has issued a Notice of Enforcement to
F-31
the Company which identifies approximately 35 items of alleged
violations of Texas environmental regulations. The Company anticipates
that penalties will be proposed with respect to these matters, but no
amounts have yet been specified.
In June 1999, CITGO and numerous other industrial companies received
notice from the U.S. EPA that the U.S. EPA believes these companies
have contributed to contamination in the Calcasieu Estuary, in the
proximity of Lake Charles, Calcasieu Parish, Louisiana and are
Potentially Responsible Parties ("PRPs") under the Comprehensive
Environmental Response, Compensation, and Liability Act ("CERCLA"). The
U.S. EPA made a demand for payment of its past investigation costs from
CITGO and other PRPs and is conducting a Remedial
Investigation/Feasibility Study ("RI/FS") under its CERCLA authority.
CITGO and other PRPs may be potentially responsible for the costs of
the RI/FS, subsequent remedial actions and natural resource damages.
CITGO disagrees with the U.S. EPA's allegations and intends to contest
this matter.
In January and July 2001, CITGO received Notices of Violation ("NOVs")
from the U.S. EPA alleging violations of the Federal Clean Air Act. The
NOVs are an outgrowth of an industry-wide and multi-industry U.S. EPA
enforcement initiative alleging that many refineries and electric
utilities modified air emission sources without obtaining permits or
installing new control equipment under the New Source Review provisions
of the Clean Air Act. The NOVs followed inspections and formal
Information Requests regarding the Company's Lake Charles, Louisiana
and Corpus Christi, Texas refineries and the Lemont, Illinois refinery.
Since mid-2002, CITGO has been engaged in settlement negotiations with
the U.S. EPA. The settlement negotiations have focused on different
levels of air pollutant emission reductions and the merits of various
types of control equipment to achieve those reductions. No settlement
agreement, or agreement in principal, has been reached. Based primarily
on the costs of control equipment reported by the U.S. EPA and other
petroleum companies and the types and number of emission control
devices that have been agreed to in previous petroleum companies' NSR
settlement with the U.S. EPA, CITGO estimates that the capital costs of
a settlement with the U.S. EPA could range from $130 million to $200
million. Any such capital costs would be incurred over a period of
years, anticipated to be from 2003 to 2008. Also, this cost estimate
range, while based on current information and judgment, is dependent on
a number of subjective factors, including the types of control devices
installed, the emission limitations set for the units the year the
technology may be installed, and possible future operational changes.
CITGO also may be subject to possible penalties. If settlement
discussions fail, CITGO is prepared to contest the NOVs. If CITGO is
found to have violated the provisions cited in the NOVs CITGO estimates
the capital expenditures or penalties that might result could range up
to $290 million to be incurred over a period of years if a court makes
a number of legal interpretations that are adverse to CITGO.
In June 1999, an NOV was issued by the U.S. EPA alleging violations of
the National Emission Standards for Hazardous Air Pollutants
regulations covering benzene emissions from wastewater treatment
operations at the Lemont, Illinois refinery operated by CITGO. CITGO is
in settlement discussions with the U.S. EPA. The Company believes this
matter will be consolidated with the matters described in the previous
paragraph.
In June 2002, a Consolidated Compliance Order and Notice of Potential
Penalty was issued by the LDEQ alleging violations of the Louisiana air
quality regulations at the Lake Charles, Louisiana refinery. CITGO is
in settlement discussions with the LDEQ.
Various regulatory authorities have the right to conduct, and from time
to time do conduct, environmental compliance audits of the Company's
and its subsidiaries' facilities and operations. Those audits have the
potential to reveal matters that those authorities believe represent
non-compliance in one or more respects with regulatory requirements and
for which those authorities may seek corrective
F-32
actions and/or penalties in an administrative or judicial proceeding.
Other than matters described above, based upon current information, the
Company is not aware that any such audits or their findings have
resulted in the filing of such a proceeding or is the subject of a
threatened filing with respect to such a proceeding, nor does the
Company believe that any such audit or their findings will have a
material adverse effect on its future business and operating results.
Conditions which require additional expenditures may exist with respect
to various Company sites including, but not limited to, CITGO's
operating refinery complexes, former refinery sites, service stations
and crude oil and petroleum product storage terminals. The amount of
such future expenditures, if any, is indeterminable.
Increasingly stringent environmental regulatory provisions and
obligations periodically require additional capital expenditures.
During 2002, CITGO spent approximately $148 million for environmental
and regulatory capital improvements in its operations. Management
currently estimates that CITGO will spend approximately $1.3 billion
for environmental and regulatory capital projects over the five-year
period 2003-2007. These estimates may vary due to a variety of factors.
SUPPLY AGREEMENTS - The Company purchases the crude oil processed at
its refineries and also purchases refined products to supplement the
production from its refineries to meet marketing demands and resolve
logistical issues. In addition to supply agreements with various
affiliates (Notes 3 and 5), the Company has various other crude oil,
refined product and feedstock purchase agreements with unaffiliated
entities with terms ranging from monthly to annual renewal. The Company
believes these sources of supply are reliable and adequate for its
current requirements.
THROUGHPUT AGREEMENTS - The Company has throughput agreements with
certain pipeline affiliates (Note 9). These throughput agreements may
be used to secure obligations of the pipeline affiliates. Under these
agreements, the Company may be required to provide its pipeline
affiliates with additional funds through advances against future
charges for the shipping of petroleum products. The Company currently
ships on these pipelines and has not been required to advance funds in
the past. At December 31, 2002, the Company has no fixed and
determinable, unconditional purchase obligations under these
agreements.
COMMODITY DERIVATIVE ACTIVITY - As of December 31, 2002 the Company's
petroleum commodity derivatives included exchange traded futures
contracts, forward purchase and sale contracts, exchange traded and
over-the-counter options, and over-the-counter swaps. At December 31,
2002, the balance sheet captions other current assets and other current
liabilities include $29.5 million and $32.9 million, respectively,
related to the fair values of open commodity derivatives.
F-33
GUARANTEES - As of December 31, 2002, the Company has guaranteed the
debt of others in a variety of circumstances including letters of
credit issued for an affiliate, bank debt of an affiliate, bank debt of
an equity investment, bank debt of customers and customer debt related
to the acquisition of marketing equipment as shown in the following
table:
(000s OMITTED)
Letters of credit $50,740
Bank debt
Affiliate 10,000
Equity investment 5,500
Customers 4,471
Financing debt of customers
Equipment acquisition 2,766
-------
Total $73,477
=======
In each case, if the debtor fails to meet its obligation, CITGO would
be obligated to make the required payment. The guarantees related to
letters of credit, affiliate's bank debt and equity investment bank
debt expire in 2003. The guarantees related to customer bank debt
expire between 2004 and 2009. The guarantees related to financing debt
associated with equipment acquisition by customers expire between 2003
and 2007. The Company has not recorded any amounts on the Company's
balance sheet relating to these guarantees.
In the event of debtor default on the letters of credit, CITGO has been
indemnified by PDV Holding, Inc., the direct parent of PDV America. In
the event of debtor default on the affiliate's and equity investment
bank debt, CITGO has no recourse. In the event of debtor default on
customer bank debt, CITGO generally has recourse to personal guarantees
from principals or liens on property, except in one case, in which the
guaranteed amount is $170 thousand, CITGO has no recourse. In the event
of debtor default on financing debt incurred by customers, CITGO would
receive an interest in the equipment being financed after making the
guaranteed debt payment.
CITGO has granted indemnities to the buyers in connection with past
sales of product terminal facilities. These indemnities provide that
CITGO will accept responsibility for claims arising from the period in
which CITGO owned the facilities. Due to the uncertainties in this
situation, the Company is not able to estimate a liability relating to
these indemnities.
The Company has not recorded a liability on its balance sheet relating
to product warranties because historically, product warranty claims
have not been significant.
OTHER CREDIT AND OFF-BALANCE SHEET RISK INFORMATION AS OF DECEMBER 31,
2002 - The Company has outstanding letters of credit totaling
approximately $451 million, which includes $428 million related to
CITGO's tax-exempt and taxable revenue bonds and $20.3 million related
to PDVMR's pollution control bonds (Note 11).
The Company has also acquired surety bonds totaling $71 million
primarily due to requirements of various government entities. The
Company does not expect liabilities to be incurred related to such
guarantees, letters of credit or surety bonds.
F-34
Neither the Company nor the counterparties are required to
collateralize their obligations under interest rate swaps or
over-the-counter derivative commodity agreements. The Company is
exposed to credit loss in the event of nonperformance by the
counterparties to these agreements. The Company does not anticipate
nonperformance by the counterparties, which consist primarily of major
financial institutions.
Management considers the credit risk to the Company related to its
commodity and interest rate derivatives to be insignificant during the
periods presented.
15. LEASES
The Company leases certain of its Corpus Christi refinery facilities
under a capital lease. The basic term of the lease expires on January
1, 2004; however, the Company may renew the lease until January 31,
2011, the date of its option to purchase the facilities for a nominal
amount. Capitalized costs included in property, plant and equipment
related to the leased assets were approximately $209 million at
December 31, 2002 and 2001. Accumulated amortization related to the
leased assets was approximately $134 million and $126 million at
December 31, 2002 and 2001, respectively. Amortization is included in
depreciation expense.
The Company also has various noncancelable operating leases, primarily
for product storage facilities, office space, computer equipment,
vessels and vehicles. Rent expense on all operating leases totaled $102
million in 2002, $77 million in 2001, and $63 million in 2000. Future
minimum lease payments for the capital lease and noncancelable
operating leases are as follows:
CAPITAL OPERATING
LEASE LEASES TOTAL
YEAR (000's OMITTED)
2003 $ 27,375 $ 105,580 $ 132,955
2004 5,000 64,296 69,296
2005 5,000 37,171 42,171
2006 5,000 21,038 26,038
2007 5,000 14,393 19,393
Thereafter 16,000 12,659 28,659
--------- --------- ---------
Total minimum lease payments 63,375 $ 255,137 $ 318,512
========= =========
Amount representing interest 16,411
---------
Present value of minimum lease payments 46,964
Current portion (22,713)
---------
$ 24,251
=========
F-35
16. FAIR VALUE INFORMATION
The following estimated fair value amounts have been determined by the
Company, using available market information and appropriate valuation
methodologies. However, considerable judgment is necessarily required
in interpreting market data to develop the estimates of fair value.
Accordingly, the estimates presented herein are not necessarily
indicative of the amounts that the Company could realize in a current
market exchange. The use of different market assumptions and/or
estimation methodologies may have a material effect on the estimated
fair value amounts.
The carrying amounts of cash equivalents approximate fair values. The
carrying amounts and estimated fair values of the Company's other
financial instruments are as follows:
2002 2001
---------------------------- ----------------------------
CARRYING FAIR CARRYING FAIR
AMOUNT VALUE AMOUNT VALUE
(000'S OMITTED) (000'S OMITTED)
LIABILITIES:
Long-term debt $ 1,300,524 $ 1,285,795 $ 1,411,556 $ 1,423,388
DERIVATIVE AND OFF-BALANCE
SHEET FINANCIAL INSTRUMENTS -
UNREALIZED LOSSES:
Interest rate swap agreements (3,450) (3,450) (2,816) (2,816)
Guarantees of debt - (2,012) - (1,470)
Letters of credit - (6,548) - (5,903)
Surety bonds - (303) - (292)
At February 11, 2003, using current rates, the estimated fair values of
guarantees of debt and letters of credit are approximately $4.2 million
and $13.5 million, respectively.
SHORT-TERM BANK LOANS AND LONG-TERM DEBT - The fair value of short-term
bank loans and long-term debt is based on interest rates that are
currently available to the Company for issuance of debt with similar
terms and remaining maturities.
INTEREST RATE SWAP AGREEMENTS - The fair value of these agreements is
based on the estimated amount that the Company would receive or pay to
terminate the agreements at the reporting dates, taking into account
current interest rates and the current creditworthiness of the
counterparties.
GUARANTEES, LETTERS OF CREDIT AND SURETY BONDS - The estimated fair
value of contingent guarantees of third-party debt, letters of credit
and surety bonds is based on fees currently charged for similar
one-year agreements or on the estimated cost to terminate them or
otherwise settle the obligations with the counterparties at the
reporting dates.
The fair value estimates presented herein are based on pertinent
information available to management as of the reporting dates. Although
management is not aware of any factors that would significantly affect
the estimated fair value amounts, such amounts have not been
comprehensively revalued for purposes of these financial statements
since that date, and current estimates of fair value may differ
significantly from the amounts presented herein.
F-36
17. CHANGE IN REPORTING ENTITY
On January 1, 2002, PDV America, the parent company of CITGO, made a
contribution to the capital of CITGO of all of the common stock of PDV
America's wholly owned subsidiary, VPHI. No additional shares of the
capital stock of CITGO were issued in connection with the contribution.
The principal asset of VPHI is a petroleum refinery owned by its wholly
owned subsidiary, PDVMR, located in Lemont, Illinois. CITGO has
operated this refinery and purchased substantially all of its primary
output, consisting of transportation fuels and petrochemicals, since
1997.
Effective January 1, 2002, the accounts of VPHI were included in the
consolidated financial statements of CITGO at the historical carrying
value of PDV America's investment in VPHI. CITGO recorded the effects
of this transaction in a manner similar to pooling-of-interests
accounting; accordingly the accompanying financial statements and notes
thereto have been restated to present the Company's consolidated
financial position as of December 31, 2001 and results of operations
for the years ended December 31, 2001 and 2000 as if the transaction
had occurred on January 1, 2000. All significant intercompany
transactions, balances and profits were eliminated; no other
adjustments to previously reported results of operations of either
entity were necessary in preparation of the restated financial
statements.
The following presents the separate results of operations for CITGO and
VPHI for the years ended December 31, 2001 and 2000:
YEAR ENDED DECEMBER 31,
-----------------------
2001 2000
(000'S OMITTED)
CITGO net income as previously reported $317,024 $231,984
Effect of VPHI 88,160 80,026
-------- --------
Net income restated $405,184 $312,010
======== ========
The restated results of operations do not purport to be indicative of
the results of operations that actually would have resulted had the
combination occurred on January 1, 2000, or of future results of
operations of the combined entities.
F-37
18. INSURANCE RECOVERIES
On August 14, 2001, a fire occurred at the crude oil distillation unit
of the Lemont refinery. The crude unit was destroyed and the refinery's
other processing units were temporarily taken out of production. A new
crude unit was operational at the end of May 2002.
On September 21, 2001, a fire occurred at the hydrocracker unit of the
Lake Charles refinery. The hydrocracker unit was damaged and operations
at other processing units were temporarily affected. Operation of the
other refinery units returned to normal on October 16, 2001. Operations
at the hydrocracker resumed on November 22, 2001.
The Company recognizes property damage insurance recoveries in excess
of the amount of recorded losses and related expenses, and business
interruption insurance recoveries when such amounts are realized.
During the years ended December 31, 2002 and 2001, the Company recorded
$407 million and $52 million, respectively, of insurance recoveries
related to these fires. Additionally, during 2001, the Company recorded
in other income (expense), property losses and related expenses
totaling $54.3 million related to these fires. The Company received
cash proceeds of $442 million and $29 million during the years ended
December 31, 2002 and 2001. The Company expects to recover additional
amounts related to the Lemont refinery event subject to final
settlement negotiations.
******
F-38
REPORT OF INDEPENDENT ACCOUNTANTS
To the Partnership Governance Committee
of LYONDELL-CITGO Refining LP
In our opinion, the accompanying balance sheets and related statements of
income, Partners' capital and cash flows present fairly, in all material
respects, the financial position of LYONDELL-CITGO Refining LP (the Partnership)
at December 31, 2002 and December 31, 2001, and the results of its operations
and its cash flows for each of the three years in the period ended December 31,
2002 in conformity with accounting principles generally accepted in the United
States of America. These financial statements are the responsibility of the
Partnership's management; our responsibility is to express an opinion on these
financial statements based on our audits. We conducted our audits of these
statements in accordance with auditing standards generally accepted in the
United States of America, which 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, assessing
the accounting principles used and significant estimates made by management and
evaluating the overall financial statement presentation. We believe that our
audits provide a reasonable basis for our opinion.
/s/ PricewaterhouseCoopers LLP
PRICEWATERHOUSECOOPERS LLP
Houston, Texas
February 14, 2003
F-39
LYONDELL-CITGO REFINING LP
STATEMENTS OF INCOME
FOR THE YEAR ENDED DECEMBER 31,
---------------------------------
MILLIONS OF DOLLARS 2002 2001 2000
- ------------------- ------- ------- -------
SALES AND OTHER OPERATING REVENUES $ 3,392 $ 3,284 $ 4,075
OPERATING COSTS AND EXPENSES:
Cost of sales:
Crude oil and feedstock 2,546 2,379 3,246
Operating and other expenses 547 588 580
Selling, general and administrative expenses 53 61 60
------- ------- -------
3,146 3,028 3,886
------- ------- -------
Operating income 246 256 189
Interest expense (32) (52) (63)
Interest income -- 1 2
------- ------- -------
Income before extraordinary items 214 205 128
Extraordinary loss on extinguishment of debt (1) (2) --
------- ------- -------
NET INCOME $ 213 $ 203 $ 128
======= ======= =======
See Notes to Financial Statements.
F-40
LYONDELL-CITGO REFINING LP
BALANCE SHEETS
DECEMBER 31,
--------------------
MILLIONS OF DOLLARS 2002 2001
- ------------------- ------- -------
ASSETS
Current assets:
Cash and cash equivalents $ 101 $ 3
Accounts receivable:
Trade, net 47 31
Related parties and affiliates 106 62
Inventories 93 130
Prepaid expenses and other current assets 10 4
------- -------
Total current assets 357 230
------- -------
Property, plant and equipment 2,392 2,322
Construction projects in progress 159 177
Accumulated depreciation and amortization (1,239) (1,156)
------- -------
1,312 1,343
Deferred charges and other assets 88 97
------- -------
Total assets $ 1,757 $ 1,670
======= =======
LIABILITIES AND PARTNERS' CAPITAL
Current liabilities:
Accounts payable:
Trade $ 69 $ 117
Related parties and affiliates 212 98
Distribution payable to Lyondell Partners 106 17
Distribution payable to CITGO Partners 75 12
Loan payable to bank -- 50
Taxes, payroll and other liabilities 52 91
------- -------
Total current liabilities 514 385
------- -------
Long-term debt 450 450
Loan payable to Lyondell Partners 229 229
Loan payable to CITGO Partners 35 35
Pension, postretirement benefit and other liabilities 126 79
------- -------
Total long-term liabilities 840 793
------- -------
Commitments and contingencies
Partners' capital:
Partners' accounts 432 507
Accumulated other comprehensive loss (29) (15)
------- -------
Total partners' capital 403 492
------- -------
Total liabilities and partners' capital $ 1,757 $ 1,670
======= =======
See Notes to Financial Statements.
F-41
LYONDELL-CITGO REFINING LP
STATEMENTS OF CASH FLOWS
FOR THE YEAR ENDED DECEMBER 31,
-------------------------------
MILLIONS OF DOLLARS 2002 2001 2000
- ------------------- -------- -------- --------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income $ 213 $ 203 $ 128
Adjustments to reconcile net income to
cash provided by operating activities:
Depreciation and amortization 116 108 112
Net loss (gain) on disposition of assets 1 (3) 1
Extraordinary items 1 2 --
Changes in assets and liabilities that provided (used) cash:
Accounts receivable (59) 113 (62)
Inventories 37 (40) (43)
Accounts payable 70 (88) 97
Prepaid expenses and other current assets (5) 7 10
Other assets and liabilities (13) (22) (21)
----- ----- -----
Cash provided by operating activities 361 280 222
----- ----- -----
CASH FLOWS FROM INVESTING ACTIVITIES:
Expenditures for property, plant and equipment (65) (109) (60)
Proceeds from sale of property, plant and equipment 2 8 --
Proceeds from sales tax refund related to capital expenditures -- 5 --
Other (3) -- (1)
----- ----- -----
Cash used in investing activities (66) (96) (61)
----- ----- -----
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from (repayment of) bank loan (50) 30 20
Contributions from Lyondell Partners 46 45 25
Contributions from CITGO Partners 32 32 18
Distributions to Lyondell Partners (126) (165) (144)
Distributions to CITGO Partners (89) (116) (101)
Payment of debt issuance costs (10) (8) --
Repayment of current maturities of long-term debt -- -- (450)
Proceeds from PDVSA loan -- -- 439
Proceeds from Lyondell Partners' loans -- -- 4
Proceeds from CITGO Partners' loans -- -- 13
----- ----- -----
Cash used in financing activities (197) (182) (176)
----- ----- -----
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 98 2 (15)
Cash and cash equivalents at beginning of period 3 1 16
----- ----- -----
Cash and cash equivalents at end of period $ 101 $ 3 $ 1
===== ===== =====
See Notes to Financial Statements.
F-42
LYONDELL-CITGO REFINING LP
STATEMENTS OF PARTNERS' CAPITAL
PARTNERS' ACCOUNTS ACCUMULATED
----------------------------- OTHER
LYONDELL CITGO COMPREHENSIVE COMPREHENSIVE
MILLIONS OF DOLLARS PARTNERS PARTNERS TOTAL INCOME (LOSS) INCOME (LOSS)
- ------------------- -------- -------- ----- ------------- --------------
BALANCE AT JANUARY 1, 2000 $ 20 $ 536 $ 556 $ -- $ --
Net income 86 42 128 -- 128
Cash contributions 25 18 43 -- --
Distributions to Partners (128) (91) (219) -- --
----- ----- ----- ----- -----
Comprehensive income $ 128
=====
BALANCE AT DECEMBER 31, 2000 3 505 508 -- $ --
Net income 129 74 203 -- 203
Cash contributions 45 32 77 -- --
Distributions to Partners (165) (116) (281) -- --
Other comprehensive income:
Minimum pension liability (15) (15)
----- ----- ----- ----- -----
Comprehensive income $ 188
=====
BALANCE AT DECEMBER 31, 2001 12 495 507 (15) $ --
Net income 135 78 213 -- 213
Cash contributions 46 32 78 -- --
Distributions to Partners (215) (151) (366) -- --
Other comprehensive income:
Minimum pension liability (14) (14)
----- ----- ----- ----- -----
Comprehensive income $ 199
=====
BALANCE AT DECEMBER 31, 2002 $ (22) $ 454 $ 432 $ (29)
===== ===== ===== =====
See Notes to Financial Statements.
F-43
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS
1. THE PARTNERSHIP
LYONDELL-CITGO Refining LP ("LCR" or the "Partnership") was formed on July 1,
1993, by subsidiaries of Lyondell Chemical Company ("Lyondell") and CITGO
Petroleum Corporation ("CITGO") in order to own and operate a refinery
("Refinery") located adjacent to the Houston Ship Channel in Houston, Texas and
a lube oil blending and packaging plant in Birmingport, Alabama.
Lyondell owns its interest in the Partnership through wholly owned subsidiaries,
Lyondell Refining Partners, LP ("Lyondell LP") and Lyondell Refining Company
("Lyondell GP"). Lyondell LP and Lyondell GP together are known as Lyondell
Partners. CITGO holds its interest through CITGO Refining Investment Company
("CITGO LP") and CITGO Gulf Coast Refining, Inc. ("CITGO GP"), both wholly owned
subsidiaries of CITGO. CITGO LP and CITGO GP together are known as CITGO
Partners. Lyondell Partners and CITGO Partners together are known as the
Partners. LCR will continue in existence until it is dissolved under the terms
of the Limited Partnership Agreement (the "Agreement").
The Partners have agreed to allocate cash distributions based on an ownership
interest that is determined by certain contributions instead of allocating such
amounts based on their capital account balances. Based upon these contributions,
Lyondell Partners and CITGO Partners had ownership interests of approximately
59% and 41%, respectively, as of December 31, 2002. Net income before
depreciation, as shown on the statements of partners' capital is allocated to
the partners based on ownership interests, while depreciation is allocated to
the partners based on contributed assets.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Revenue Recognition--Revenue from product sales is recognized as risk and title
to the product transfer to the customer, which usually occurs when shipment is
made.
Cash and Cash Equivalents--Cash equivalents consist of highly liquid debt
instruments such as certificates of deposit, commercial paper and money market
accounts. Cash equivalents include instruments with an original maturity date of
three months or less. Cash equivalents are stated at cost, which approximates
fair value. The Partnership's policy is to invest cash in conservative, highly
rated instruments and limit the amount of credit exposure to any one
institution.
Accounts Receivable--The Partnership sells its products primarily to other
industrial concerns in the petrochemical and refining industries. The
Partnership performs ongoing credit evaluations of its customers' financial
condition and in certain circumstances, requires letters of credit from them.
The Partnership's allowance for doubtful accounts receivable, which is reflected
in the Balance Sheets as a reduction of accounts receivable-trade, totaled
$25,000 at both December 31, 2002 and 2001.
Inventories--Inventories are stated at the lower of cost or market. Cost is
determined using the last-in, first-out ("LIFO") basis for substantially all
inventories, except for materials and supplies, which are valued using the
average cost method.
Inventory exchange transactions, which involve fungible commodities and do not
involve the payment or receipt of cash, are not accounted for as purchases and
sales. Any resulting volumetric exchange balances are accounted for as inventory
in accordance with the normal LIFO valuation policy.
F-44
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Property, Plant and Equipment--Property, plant and equipment are recorded at
cost. Depreciation is computed using the straight-line method over the estimated
useful asset lives, generally, 24 years for major manufacturing equipment, 24 to
30 years for buildings, 5 to 10 years for light equipment and instrumentation,
10 years for office furniture and 5 years for information system equipment. Upon
retirement or sale, LCR removes the cost of the asset and the related
accumulated depreciation from the accounts and reflects any resulting gain or
loss in the Statement of Income. LCR's policy is to capitalize interest cost
incurred on debt during the construction of major projects exceeding one year.
Long-Lived Asset Impairment--LCR evaluates long-lived assets for impairment
whenever events or changes in circumstances indicate that a carrying amount of
an asset may not be recoverable. When it is probable that undiscounted future
cash flows will not be sufficient to recover an asset's carrying amount, the
asset is written down to its estimated fair value. Long-lived assets to be
disposed of are reported at the lower of carrying amount or estimated fair value
less costs to sell the assets.
Turnaround Maintenance and Repair Costs--Costs of maintenance and repairs
exceeding $5 million incurred in connection with turnarounds of major units at
the Refinery are deferred and amortized using the straight-line method over the
period until the next planned turnaround, generally four to six years. These
costs are maintenance, repair and replacement costs that are necessary to
maintain, extend and improve the operating capacity and efficiency rates of the
production units. Amortization of deferred turnaround costs for 2002, 2001 and
2000 were $13 million, $11 million and $11 million, respectively. Other
turnaround costs and ordinary repair and maintenance costs were expensed as
incurred.
Environmental Remediation Costs--Anticipated expenditures related to
investigation and remediation of contaminated sites, which include operating
facilities and waste disposal sites, are accrued when it is probable a liability
has been incurred and the amount of the liability can reasonably be estimated.
Estimated expenditures have not been discounted to present value.
Income Taxes--The Partnership is not subject to federal income taxes as income
is reportable directly by the individual partners; therefore, there is no
provision for federal income taxes in the accompanying financial statements. The
Partnership is subject to certain state income taxes.
Use of Estimates--The preparation of financial statements in conformity with
generally accepted accounting principles requires management to make estimates
and assumptions that affect the reported amounts of assets and liabilities, the
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the
reporting period. Actual results could differ from those estimates.
Accounting Changes--Effective January 1, 2002, LCR implemented Statement of
Financial Accounting Standards ("SFAS") No. 141, Business Combinations, SFAS No.
142, Goodwill and Other Intangible Assets and SFAS No. 144, Accounting for the
Impairment or Disposal of Long-Lived Assets. Implementation of SFAS No. 141,
SFAS No. 142 and SFAS No. 144 did not have a material effect on the financial
statements of LCR.
Anticipated Accounting Changes--LCR expects to implement two significant
accounting changes in 2003, as discussed below.
In April 2002, the Financial Accounting Standards Board ("FASB") issued SFAS No.
145, Rescission of FASB Statement No. 4, 44 and 64, Amendment of FASB Statement
No. 13, and Technical Corrections. The primary impact of the statement on LCR,
when implemented in 2003, will be the classification of gains or losses that
result from early extinguishment of debt as an element of income before
extraordinary items. Reclassification of prior period gains or losses that were
originally reported as extraordinary items also will be required (See Note 3).
F-45
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
In January 2003, the FASB issued Interpretation No. 46 (FIN No. 46),
Consolidation of Variable Interest Entities. FIN No. 46 addresses situations in
which a company should include in its financial statements the assets,
liabilities and activities of another entity. FIN No. 46 applies immediately to
entities created after January 31, 2003 and, for LCR, will apply to older
entities beginning in the third quarter 2003. LCR does not expect FIN No. 46 to
have a significant effect on its financial statements.
Other Recent Accounting Pronouncements--In June 2001, the FASB issued SFAS No.
143, Accounting for Asset Retirement Obligations, which addresses obligations
associated with the retirement of tangible long-lived assets. In July 2002, the
FASB issued SFAS No. 146, Accounting for Exit or Disposal Activities. SFAS No.
146 addresses the recognition, measurement and reporting of costs associated
with exit and disposal activities, including restructuring activities and
facility closings. SFAS No. 146 will be effective for activities initiated after
December 31, 2002. LCR does not expect adoption of SFAS No. 143 or SFAS No. 146
to have a material impact on its financial statements.
In November 2002, the FASB issued Interpretation No. 45 (FIN No. 45),
Guarantor's Accounting and Disclosure Requirements. FIN No. 45 expands required
disclosures for certain types of guarantees for the period ended December 31,
2002 and requires recognition of a liability at fair value for guarantees
granted after December 31, 2002. LCR does not expect FIN No. 45 to have a
significant effect on its financial statements.
Reclassifications--Certain previously reported amounts have been reclassified to
conform to classifications adopted in 2002.
3. EXTRAORDINARY ITEMS
In December 2002, LCR completed the refinancing of its credit facilities with a
new $450 million term bank loan facility and a $70 million working capital
revolving credit facility prior to maturity (See Note 7). LCR wrote off
unamortized debt issuance costs of $1 million. The $1 million charge was
reported as an extraordinary loss on extinguishment of debt. Previously, these
debt issuance costs had been deferred and amortized to interest expense.
In July 2001, LCR wrote off $2 million of unamortized debt issuance costs
related to the early retirement of the $450 million term credit facility. The
charge was reported as an extraordinary loss on extinguishment of debt (See Note
7).
F-46
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
4. RELATED PARTY TRANSACTIONS
LCR is party to agreements with the following related parties:
- CITGO
- CITGO Partners
- Equistar Chemicals, LP ("Equistar") - Lyondell holds a 70.5%
interest
- Lyondell
- Lyondell Partners
- Petroleos de Venezuela, S.A. ("PDVSA")
- PDV Holding, Inc.
- PDVSA Petroleo, S.A. ("PDVSA Oil")
- PDVSA Services
- Petrozuata Financial, Inc.
- TCP Petcoke Corporation
LCR buys a substantial majority of its crude oil supply at deemed product-based
prices, adjusted for certain indexed items (See Notes 11 and 12), from PDVSA Oil
under the terms of a long-term crude oil supply agreement ("Crude Supply
Agreement").
Under the terms of a long-term product sales agreement, CITGO buys all of the
finished gasoline, jet fuel, low sulfur diesel, heating oils, coke and sulfur
produced at the Refinery at market-based prices.
LCR is party to a number of raw materials, product sales and administrative
service agreements with Lyondell, CITGO and Equistar. This includes a hydrogen
take-or-pay contract with Equistar (See Note 11). In addition, a processing
agreement provides for the production of alkylate and methyl tertiary butyl
ether for the Partnership at Equistar's Channelview, Texas petrochemical
complex.
Under the terms of a lubricant facility operating agreement, CITGO operates the
lubricant facility in Birmingport, Alabama while the Partnership retains
ownership. Under the terms of the lubricant sales agreements, CITGO buys
paraffinic lubricants base oil, naphthenic lubricants, white mineral oils and
specialty oils from the Partnership.
F-47
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Related party transactions are summarized as follows:
FOR THE YEAR ENDED DECEMBER 31,
-------------------------------
MILLIONS OF DOLLARS 2002 2001 2000
- ------------------- ------- ------ ------
LCR billed related parties for the following:
Sales of products:
CITGO $2,488 $2,309 $2,879
Equistar 217 203 264
Lyondell 1 -- --
PDVSA Services -- -- 14
TCP Petcoke Corporation 17 40 32
Services and cost sharing arrangements:
Equistar 1 2 --
Lyondell 1 3 2
Related parties billed LCR for the following:
Purchase of products:
CITGO 78 80 52
Equistar 324 359 425
Lyondell 1 -- --
PDVSA 1,259 1,474 1,796
Petrozuata 22 -- --
Transportation charges:
CITGO 1 1 1
Equistar 3 3 --
PDVSA 3 3 1
Services and cost sharing arrangements:
CITGO 8 3 2
Equistar 17 19 15
Lyondell 3 3 4
During 2002, LCR and the Partners agreed to renew and extend a number of
existing notes due to Lyondell Partners and CITGO Partners with master notes to
each Partner. These master notes replace existing notes dated on or prior to
July 31, 2000. At December 31, 2002, Lyondell Partners and CITGO Partners loans
totaled $229 million and $35 million, respectively. Both master notes are due on
December 7, 2004. In accordance with an agreement with the Partners related to
LCR's credit facility (See Note 7), no interest was paid to Lyondell Partners or
CITGO Partners on these loans during 2002 or 2001.
During 2000, LCR paid PDVSA $15 million for interest on the $450 million interim
financing from May 2000 through September 2000. During 2000, LCR paid PDV
Holding, Inc. $1 million for interest on the interim $70 million revolver loan
from May 2000 through September 2000.
5. SUPPLEMENTAL CASH FLOW INFORMATION
At December 31, 2002, 2001 and 2000, construction in progress included
approximately $6 million, $11 million and $3 million, respectively, of non-cash
additions which related to accounts payable accruals.
During 2002, 2001 and 2000, LCR paid interest of $26 million, $38 million and
$41 million, respectively. No interest costs were capitalized in 2002, 2001 or
2000. During each of the years ended December 31, 2002, 2001 and 2000, LCR paid
less than $1 million in state income tax.
F-48
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
During the third quarter 2000, LCR recorded certain non-cash financing
transactions. Proceeds from the $450 million one-year credit facility completed
in September 2000, net of approximately $11 million of loan costs, were paid
directly to the holder of the interim financing note. Also, approximately $6
million was paid by Lyondell directly to CITGO for Lyondell's share of previous
capital funding loans made by CITGO to LCR.
6. INVENTORIES
Inventories consisted of the following components at December 31:
MILLIONS OF DOLLARS 2002 2001
- ------------------- ---- ----
Finished goods $ 29 $ 42
Raw materials 51 75
Materials and supplies 13 13
---- ----
Total inventories $ 93 $130
==== ====
In 2002 and 2001, all inventory, excluding materials and supplies, were
determined by the LIFO method. The excess of replacement cost of inventories
over the carrying value was approximately $140 million and $53 million at
December 31, 2002 and 2001, respectively.
7. FINANCING ARRANGEMENTS
In December 2002, LCR completed the refinancing of its credit facilities with a
new $450 million term bank loan facility and a $70 million working capital
revolving credit facility with eighteen-month terms (See Note 3). The
facilities, secured by substantially all of the assets of LCR, will mature in
June 2004. The $450 million term bank loan facility was originally used to
partially fund an upgrade project at the Refinery which was completed in
February 1997. At December 31, 2002, $450 million was outstanding under this
credit facility with a weighted-average interest rate of 4.5%. Interest for this
facility was determined by base rates or eurodollar rates at the Partnership's
option. The $70 million working capital revolving credit facility is utilized
for general business purposes and for letters of credit. At December 31, 2002,
no amounts were outstanding under this credit facility.
The December 2002 refinancing replaced an eighteen-month credit facility
consisting of a $450 million term loan (See Note 3) and a $70 million revolving
credit facility with a group of banks, that would have expired in January 2003.
These facilities replaced similar facilities, which would have expired in
September 2001.
At December 31, 2001, $450 million was outstanding under the $450 million term
loan with a weighted-average interest rate of 5.4%. At December 31, 2001, $50
million was outstanding under the $70 million revolving credit facility with a
weighted-average interest rate of 4.8%.
Both facilities contain covenants that require LCR to maintain a minimum net
worth and maintain certain financial ratios defined in the agreements. The
facilities also contain other customary covenants which limit the Partnership's
ability to modify certain significant contracts, incur significant additional
debt or liens, dispose of assets, make restricted payments as defined in the
agreements or merge or consolidate with other entities. LCR was in compliance
with all such covenants at December 31, 2002.
Also during the December 2002 refinancing, the Partners and LCR agreed to renew
and extend a number of existing notes due to Lyondell Partners and CITGO
Partners with master notes to each Partner. Both master notes extend the due
date to December 7, 2004 from July 1, 2003 and are subordinate to the two bank
credit facilities. At December 31, 2002, Lyondell Partners and CITGO Partners
loans totaled $229 million and $35 million, respectively, and both loans had
weighted-average interest rates of 2.2%, which were based on eurodollar rates.
At December 31, 2001, Lyondell Partners and CITGO Partners loans totaled $229
million and $35 million, respectively, and both loans had weighted-average
interest rates of 4.4%, which were based on eurodollar rates. Interest to both
Partners was paid at
F-49
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
the end of each calendar quarter through June 30, 1999, but is now deferred in
accordance with an agreement with the Partners related to the $450 million
credit facility.
At December 31, 2002, LCR had outstanding letters of credit totaling $12
million.
8. LEASE COMMITMENTS
LCR leases crude oil storage facilities, computers, office equipment and other
items under noncancelable operating lease arrangements for varying periods. As
of December 31, 2002, future minimum lease payments for the next five years and
thereafter, relating to all noncancelable operating leases with terms in excess
of one year were as follows:
MILLIONS OF DOLLARS
- -------------------
2003 $ 29
2004 12
2005 12
2006 9
2007 8
Thereafter 13
--------
Total minimum lease payments $ 83
========
Operating lease net rental expenses for the years ended December 31, 2002, 2001
and 2000 were approximately $34 million, $32 million and $31 million,
respectively.
9. FINANCIAL INSTRUMENTS
The fair value of all financial instruments included in current assets and
current liabilities, including cash and cash equivalents, accounts receivable,
accounts payable and loan payable to bank, approximated their carrying value due
to their short maturity. The fair value of long-term loans payable approximated
their carrying value because they bear interest at variable rates.
10. PENSION AND OTHER POSTRETIREMENT BENEFITS
All full-time regular employees of the Partnership are covered by defined
benefit pension plans sponsored by LCR. Retirement benefits are based on years
of service and the employee's highest three consecutive years of compensation
during the last ten years of service. LCR accrues pension costs based upon an
actuarial valuation and funds the plans through periodic contributions to
pension trust funds as required by applicable law. LCR also has one unfunded
supplemental nonqualified retirement plan, which provides pension benefits for
certain employees in excess of the tax-qualified plans' limit. In addition, LCR
sponsors unfunded postretirement benefit plans other than pensions, which
provide medical and life insurance benefits. The postretirement medical plan is
contributory, while the life insurance plan is noncontributory.
F-50
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The following table provides a reconciliation of benefit obligations, plan
assets and the funded status of the plans:
OTHER POSTRETIREMENT
PENSION BENEFITS BENEFITS
---------------- ----------------
MILLIONS OF DOLLARS 2002 2001 2002 2001
- ------------------- ----- ----- ----- -----
CHANGE IN BENEFIT OBLIGATION:
Benefit obligation, January 1 $ 97 $ 70 $ 31 $ 32
Service cost 6 5 1 1
Interest cost 8 6 2 2
Plan amendments 1 -- -- --
Actuarial loss (gain) 15 21 3 (2)
Benefits paid (3) (5) (2) (2)
----- ----- ----- -----
Benefit obligation, December 31 124 97 35 31
----- ----- ----- -----
CHANGE IN PLAN ASSETS:
Fair value of plan assets, January 1 39 42 -- --
Actual return on plan assets (5) (3) -- --
Partnership contributions 18 5 2 2
Benefits paid (3) (5) (2) (2)
----- ----- ----- -----
Fair value of plan assets, December 31 49 39 -- --
----- ----- ----- -----
Funded status (75) (58) (35) (31)
Unrecognized actuarial and investment loss 59 38 14 8
Unrecognized prior service cost (benefit) 3 2 (19) (22)
----- ----- ----- -----
Net amount recognized $ (13) $ (18) $ (40) $ (45)
===== ===== ===== =====
AMOUNTS RECOGNIZED IN BALANCE SHEETS:
Accrued benefit liability $ (13) $ (18) $ (40) $ (45)
Additional minimum liability (32) (17) -- --
Intangible asset 3 2 -- --
Accumulated other comprehensive income 29 15 -- --
----- ----- ----- -----
Net amount recognized $ (13) $ (18) $ (40) $ (45)
===== ===== ===== =====
Pension plans with projected and accumulated benefit obligations in excess of
the fair value of assets are summarized as follows at December 31:
MILLIONS OF DOLLARS 2002 2001
- ------------------- ------ ------
Projected benefit obligations $ 123 $ 97
Accumulated benefit obligations 93 74
Fair value of assets 49 39
F-51
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
Net periodic pension and other postretirement benefit costs included the
following components:
OTHER POSTRETIREMENT
PENSION BENEFITS BENEFITS
------------------------ ------------------------
MILLIONS OF DOLLARS 2002 2001 2000 2002 2001 2000
- ------------------- ---- ---- ---- ---- ---- ----
COMPONENTS OF NET PERIODIC
BENEFIT COST:
Service cost $ 6 $ 5 $ 4 $ 1 $ 1 $ 1
Interest cost 8 6 6 2 2 2
Actual loss on plan assets 5 3 2 -- -- --
Less-unrecognized loss (9) (7) (5) -- -- --
---- ---- ---- ---- ---- ----
Recognized gain on plan assets (4) (4) (3) -- -- --
Amortization of prior service costs -- -- -- (3) (3) (3)
Amortization of actuarial and
investment loss 3 2 -- 1 -- 1
Net effect of curtailments,
settlements and special
termination benefits -- -- 2 -- 1 --
---- ---- ---- ---- ---- ----
Net periodic benefit cost $ 13 $ 9 $ 9 $ 1 $ 1 $ 1
==== ==== ==== ==== ==== ====
Special termination benefit charge $ -- $ -- $ 1 $ -- $ -- $ --
==== ==== ==== ==== ==== ====
The assumptions used in determining net pension cost and net pension liability
were as follows at December 31:
OTHER POSTRETIREMENT
PENSION BENEFITS BENEFITS
------------------------------- ---------------------------------
2002 2001 2000 2002 2001 2000
----- ----- ----- ----- ----- -----
Discount rate 6.50% 7.00% 7.50% 6.50% 7.00% 7.50%
Expected return on plan assets 9.50% 9.50% 9.50% N/A N/A N/A
Rate of compensation increase 4.50% 4.50% 4.50% 4.50% 4.50% 4.50%
The assumed annual rate of increase in the per capita cost of covered health
care benefits as of December 31, 2002 was 10% for 2003 through 2004, 7% for 2005
through 2007 and 5% thereafter. The health care cost trend rate assumption does
not have a significant effect on the amounts reported due to limits on LCR's
maximum contribution level to the medical plan. To illustrate, increasing or
decreasing the assumed health care cost trend rates by one percentage point in
each year would not change the accumulated postretirement benefit liability as
of December 31, 2002 and would not have a material effect on the aggregate
service and interest cost components of the net periodic postretirement benefit
cost for the year then ended.
LCR also maintains voluntary defined contribution savings plans for eligible
employees. Contributions to the plans by LCR were $5 million in each of the
three years ended December 31, 2002.
F-52
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
11. COMMITMENTS AND CONTINGENCIES
Commitments--LCR has various purchase commitments for materials, supplies and
services incident to the ordinary conduct of business, generally for quantities
required for LCR's business and at prevailing market prices. LCR is party to
various unconditional purchase obligation contracts as a purchaser for products
and services, principally take-or-pay contracts for hydrogen, electricity and
steam. At December 31, 2002, future minimum payments under these contracts with
noncancelable contract terms in excess of one year and fixed minimum payments
were as follows:
MILLIONS OF DOLLARS
- -------------------
2003 $ 49
2004 45
2005 43
2006 44
2007 46
Thereafter through 2021 419
--------
Total minimum contract payments $ 646
========
Total LCR purchases under these agreements were $68 million, $94 million and $78
million during 2002, 2001 and 2000, respectively. A substantial portion of the
future minimum payments and purchases were related to a hydrogen take-or-pay
agreement with Equistar (See Note 4).
Crude Supply Agreement--Under the Crude Supply Agreement ("CSA"), which will
expire on December 31, 2017, PDVSA Oil is required to sell, and LCR is required
to purchase 230,000 barrels per day of extra heavy Venezuelan crude oil, which
constitutes approximately 86% of the Refinery's refining capacity of 268,000
barrels per day of crude oil (See Note 4). Since April 1998, PDVSA Oil has, from
time to time, declared itself in a force majeure situation and subsequently
reduced deliveries of crude oil. Such reductions in deliveries were purportedly
based on announced OPEC production cuts. PDVSA Oil informed LCR that the
Venezuelan government, through the Ministry of Energy and Mines, had instructed
that production of certain grades of crude oil be reduced. In certain
circumstances, PDVSA Oil made payments under a different provision of the CSA in
partial compensation for such reductions.
In January 2002, PDVSA Oil again declared itself in a force majeure situation
and stated that crude oil deliveries could be reduced by up to 20.3% beginning
March 1, 2002. Beginning in March 2002, deliveries of crude oil to LCR were
reduced to approximately 198,000 barrels per day, reaching a level of 190,000
barrels per day during the second quarter 2002. Crude oil deliveries to LCR
under the CSA increased to the contract level of 230,000 barrels per day during
the third quarter of 2002, averaging 212,000 barrels per day for the third
quarter. Although deliveries of crude oil increased to contract levels during
the third quarter 2002, PDVSA Oil did not revoke its January 2002 force majeure
declaration during 2002.
A national work stoppage in Venezuela began in early December 2002 and disrupted
deliveries of crude oil to LCR under the CSA, causing LCR to temporarily reduce
operating rates. PDVSA Oil again declared a force majeure and reduced deliveries
of crude oil to LCR. LCR compensated for the loss in supply by reducing its
inventories of CSA crude oil and increasing purchases of crude oil in the
merchant market (See Note 12). Recent media reports indicate that the force
majeure has been lifted.
LCR has consistently contested the validity of PDVSA Oil's and PDVSA's
reductions in deliveries under the CSA. The parties have different
interpretations of the provisions of the contracts concerning the delivery of
crude oil. The contracts do not contain dispute resolution procedures and the
parties have been unable to resolve their commercial
F-53
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
dispute. As a result, on February 1, 2002, LCR filed a lawsuit against PDVSA and
PDVSA Oil in connection with the force majeure declarations. From time to time,
Lyondell and PDVSA have had discussions covering both a restructuring of the CSA
and a broader restructuring of the LCR partnership. LCR is unable to predict
whether changes in either arrangement will occur.
Subject to the consent of the other partner and rights of first offer and first
refusal, the Partners each have a right to transfer their interest in LCR to
unaffiliated third parties in certain circumstances. In the event that CITGO
were to transfer its interest in LCR to an unaffiliated third party, PDVSA Oil
would have an option to terminate the CSA.
Depending on then-current market conditions, any breach or termination of the
CSA, or reduction in supply thereunder, would require LCR to purchase all or a
portion of its crude oil feedstocks in the merchant market, could subject LCR to
significant volatility and price fluctuations and could adversely affect the
Partnership. There can be no assurance that alternative crude oil supplies with
similar margins would be available for purchase by LCR.
Environmental Remediation--With respect to liabilities associated with the
Refinery, Lyondell generally has retained liability for events that occurred
prior to July 1, 1993 and certain ongoing environmental projects at the Refinery
under the Contribution Agreement, retained liability section. LCR generally is
responsible for liabilities associated with events occurring after June 30, 1993
and ongoing environmental compliance inherent to the operation of the Refinery.
LCR's policy is to be in compliance with all applicable environmental laws. LCR
is subject to extensive national, state and local environmental laws and
regulations concerning emissions to the air, discharges onto land or waters and
the generation, handling, storage, transportation, treatment and disposal of
waste materials. Many of these laws and regulations provide for substantial
fines and potential criminal sanctions for violations. Some of these laws and
regulations are subject to varying and conflicting interpretations. In addition,
the Partnership cannot accurately predict future developments, such as
increasingly strict environmental laws, inspection and enforcement policies, as
well as higher compliance costs therefrom, which might affect the handling,
manufacture, use, emission or disposal of products, other materials or hazardous
and non-hazardous waste. Some risk of environmental costs and liabilities is
inherent in particular operations and products of the Partnership, as it is with
other companies engaged in similar businesses, and there is no assurance that
material costs and liabilities will not be incurred. In general, however, with
respect to the capital expenditures and risks described above, the Partnership
does not expect that it will be affected differently than the rest of the
refining industry where LCR is located.
LCR estimates that it has a liability of approximately $1 million at December
31, 2002 related to future assessment and remediation costs. Lyondell has a
contractual obligation to reimburse LCR for approximately half of this
liability. Accordingly, LCR has reflected a current liability for the remaining
portion of this liability that will not be reimbursed by Lyondell. In the
opinion of management, there is currently no material estimable range of loss in
excess of the amount recorded. However, it is possible that new information
associated with this liability, new technology or future developments such as
involvement in investigations by regulatory agencies, could require LCR to
reassess its potential exposure related to environmental matters.
Clean Air Act--The eight-county Houston/Galveston region has been designated a
severe non-attainment area for ozone by the U.S. Environmental Protection Agency
("EPA"). Emission reduction controls for nitrogen oxides ("NOx") must be
installed at the Refinery located in the Houston/Galveston region during the
next several years. Recently adopted revisions by the regulatory agencies
changed the required NOx reduction levels from 90% to 80%. Under the previous
90% reduction standard, LCR estimated that aggregate related capital
expenditures could total between $130 million and $150 million before the 2007
deadline. Under the revised 80% standard, LCR estimates that capital
expenditures would decrease to between $50 million and $55 million. However, the
savings from this revision could be offset by costs of stricter proposed
controls over highly reactive, volatile organic compounds ("HRVOC"). LCR is
still assessing the impact of the proposed HRVOC revisions and there can be no
guarantee as to the ultimate capital cost of implementing any final plan
developed to ensure ozone attainment by the 2007 deadline. The timing and amount
of these expenditures are also subject to regulatory and other uncertainties, as
well as obtaining the necessary permits and approvals.
F-54
LYONDELL-CITGO REFINING LP
NOTES TO FINANCIAL STATEMENTS--(CONTINUED)
The Clean Air Act also specified certain emissions standards for vehicles, and
in 1998, the EPA concluded that additional controls on gasoline and diesel fuel
were necessary. New standards for gasoline were finalized in 1999 and will
require refiners to produce a low sulfur gasoline by 2004, with final compliance
by 2006. A new "on-road" diesel standard was adopted in January 2001 and will
require refiners to produce ultra low sulfur diesel by June 2006, with some
allowance for a conditional phase-in period that could extend final compliance
until 2009. LCR estimates that these standards will result in increased capital
investment totaling between $175 million to $225 million for the new gasoline
standards and between $250 million to $300 million for the new diesel standard,
between now and the implementation dates. In addition, these standards could
result in higher operating costs.
General--LCR is involved in various lawsuits and proceedings. Subject to the
uncertainty inherent in all litigation, management believes the resolution of
these proceedings will not have a material adverse effect on the financial
position, liquidity or results of operations of LCR.
In the opinion of management, any liability arising from the matters discussed
in this note is not expected to have a material adverse effect on the financial
position or liquidity of LCR. However, the adverse resolution in any reporting
period of one or more of these matters discussed in this note could have a
material impact on LCR's results of operations for that period without giving
effect to contribution or indemnification obligations of codefendants or others,
or to the effect of any insurance coverage that may be available to offset the
effects of any such award.
12. SUBSEQUENT EVENT
Due to the national work stoppage in Venezuela that began in early December
2002, the resulting force majeure declared by PDVSA Oil and the related
reduction of CSA crude oil deliveries, LCR began purchasing significant volumes
of crude oil in the merchant market in late December 2002 and January 2003 (See
Note 11). As a result of these merchant market purchases and the lower CSA
deliveries, LCR operated at approximately 70% of capacity in January 2003.
Operating rates returned to 265,000 barrels per day beginning in February 2003
as CSA deliveries returned to the contractual level, despite the force majeure
declaration. Given the uncertainties surrounding the restoration of normal
operations at PDVSA, future effects on the CSA cannot be determined. Recent
media reports indicate that the force majeure has been lifted.
F-55
Exchange Offer for
$550,000,000
11 3/8% Senior Notes due 2011
(CITGO PETROLEUM CORPORATION LOGO)
------------------------
PROSPECTUS
------------------------
September 9, 2003
Until October 22, 2003, all dealers that effect transactions in these
securities, whether or not participating in this offering, may be required to
deliver a prospectus. This is in addition to the dealers' obligation to deliver
a prospectus when acting as underwriters and with respect to their unsold
allotments or subscriptions.