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United States
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
FORM 10-Q
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 0R 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2003
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the transition period from ____________ to ____________
COMMISSION FILE NUMBER 1-14380
CITGO PETROLEUM CORPORATION
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(Exact name of registrant as specified in its charter)
DELAWARE 73-1173881
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(State or other jurisdiction of (I. R. S. Employer Identification No.)
incorporation or organization)
ONE WARREN PLACE, 6100 SOUTH YALE AVENUE, TULSA, OKLAHOMA 74136
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(Address of principal executive office) (Zip Code)
(918) 495-4000
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(Registrant's telephone number, including area code)
N. A.
- --------------------------------------------------------------------------------
(Former name, former address and former fiscal year, if changed since
last report)
Indicate by check mark whether the registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the
Securities Exchange Act of 1934 during the preceding 12 months
(or for such shorter period that the registrant was required to file such
reports), and (2) has been subject to such filing requirements for the past 90
days. Yes [X] No [ ]
Indicate by check mark whether the registrant is an accelerated filer (as
described in Rule 12b-2 of the Act): Yes [ ] No [X]
Indicate the number of shares outstanding of each of the issuer's classes of
common stock, as of the latest practicable date.
COMMON STOCK, $1.00 PAR VALUE 1,000
- ----------------------------- -----
(Class) (outstanding at October 31, 2003)
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CITGO PETROLEUM CORPORATION
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2003
TABLE OF CONTENTS
PAGE
FACTORS AFFECTING FORWARD LOOKING STATEMENTS......................................................................... 1
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements (Unaudited)
Condensed Consolidated Balance Sheets - September 30, 2003 and
December 31, 2002...................................................................................... 2
Condensed Consolidated Statements of Income and Comprehensive Income -
Three and Nine-Month Periods Ended September 30, 2003 and 2002......................................... 3
Condensed Consolidated Statement of Shareholder's Equity - Nine-Month Period
Ended September 30, 2003............................................................................... 4
Condensed Consolidated Statements of Cash Flows - Nine-Month Periods Ended
September 30, 2003 and 2002............................................................................ 5
Notes to the Condensed Consolidated Financial Statements............................................... 6
Item 2. Management's Discussion and Analysis of Financial Condition and
Results of Operations.................................................................................. 17
Item 3. Quantitative and Qualitative Disclosures About Market Risk............................................. 24
Item 4. Controls and Procedures................................................................................ 28
PART II. OTHER INFORMATION
Item 1. Legal Proceedings...................................................................................... 29
Item 6. Exhibits and Reports on Form 8-K....................................................................... 29
SIGNATURES........................................................................................................... 30
FACTORS AFFECTING FORWARD LOOKING STATEMENTS
This Report contains "forward looking statements" within the meaning of
Section 27A of the Securities Act of 1933, as amended, and Section 21E of the
Securities Exchange Act of 1934, as amended. Specifically, all statements under
the caption "Item 2 - Management's Discussion and Analysis of Financial
Condition and Results of Operations" pertaining to capital expenditures and
investments related to environmental compliance, strategic planning, purchasing
patterns of refined products and capital resources available to CITGO Petroleum
Corporation ("CITGO", "our Company", "we", "us", "our", or similar references)
are forward looking statements. In addition, when used in this document, the
words "anticipate," "estimate," "project," "believe" and similar expressions are
used to identify forward looking statements.
Those forward looking statements are subject to risks and uncertainties
that could cause actual results to differ materially from the forward looking
statements. Those risks and uncertainties include changes in the availability
and cost of crude oil, feedstocks, blending components and refined products;
changes in prices or demand for our products as a result of competitive actions
or economic factors; changes in environmental and other regulatory requirements,
which may affect operations, operating costs and capital expenditure
requirements; costs and uncertainties associated with technological change and
implementation; inflation; and continued access to capital markets and
commercial bank financing on favorable terms. In addition, we purchase a
significant portion of our crude oil requirements from Petroleos de Venezuela,
S.A. (as defined herein), our ultimate parent corporation, under long-term
supply agreements, and could be adversely affected by social, economic and
political conditions in Venezuela. (See Exhibit 99.4 to the Form 8-K filed by
CITGO on February 25, 2003 for additional information concerning risk factors).
Readers are cautioned not to place undue reliance on these forward
looking statements, which speak only as of the date of this Report. We undertake
no obligation to publicly release any revision to these forward looking
statements to reflect events or circumstances after the date of this Report.
1
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)
CITGO PETROLEUM CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
(DOLLARS IN THOUSANDS)
SEPTEMBER 30,
2003 DECEMBER 31,
(UNAUDITED) 2002
-------------------------------------
ASSETS
CURRENT ASSETS:
Cash and cash equivalents $ 131,089 $ 33,025
Accounts receivable, net 1,034,931 905,178
Due from affiliates 66,232 93,615
Inventories 962,106 1,090,915
Prepaid expenses and other 63,837 64,767
------------ ------------
Total current assets 2,258,195 2,187,500
PROPERTY, PLANT AND EQUIPMENT - Net 3,874,544 3,750,166
RESTRICTED CASH 24,648 23,486
INVESTMENTS IN AFFILIATES 635,490 716,469
OTHER ASSETS 335,231 309,291
------------ ------------
$ 7,128,108 $ 6,986,912
============ ============
LIABILITIES AND SHAREHOLDER'S EQUITY
CURRENT LIABILITIES:
Accounts payable $ 670,634 $ 830,769
Payables to affiliates 489,294 417,634
Taxes other than income 233,809 229,072
Other 252,658 283,428
Income taxes payable 128,712 24,770
Current portion of long-term debt 31,364 190,664
Current portion of capital lease obligation 12,803 22,713
------------ ------------
Total current liabilities 1,819,274 1,999,050
LONG-TERM DEBT 1,420,699 1,109,861
CAPITAL LEASE OBLIGATION 23,116 24,251
POSTRETIREMENT BENEFITS OTHER THAN PENSIONS 302,268 247,762
OTHER NONCURRENT LIABILITIES 287,727 211,950
DEFERRED INCOME TAXES 863,202 834,880
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 776,503 925,114
Accumulated other comprehensive loss (24,380) (25,655)
------------ ------------
Total shareholder's equity 2,411,822 2,559,158
------------ ------------
$ 7,128,108 $ 6,986,912
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See notes to condensed consolidated financial statements.
2
CITGO PETROLEUM CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (UNAUDITED)
(DOLLARS IN THOUSANDS)
THREE MONTHS NINE MONTHS
ENDED SEPTEMBER 30, ENDED SEPTEMBER 30,
------------------- -------------------
2003 2002 2003 2002
---- ---- ---- ----
REVENUES:
Net sales $6,430,568 $5,342,794 $18,595,453 $13,698,780
Sales to affiliates 71,763 67,777 303,627 176,654
---------- ---------- ----------- -----------
6,502,331 5,410,571 18,899,080 13,875,434
Equity in earnings of affiliates 35,398 28,132 79,973 77,405
Insurance recoveries 1,863 46,326 146,165 256,867
Other income (expense) - net 1,208 (11,492) 16,899 (26,002)
---------- ---------- ----------- -----------
Total revenues 6,540,800 5,473,537 19,142,117 14,183,704
---------- ---------- ----------- -----------
COST OF SALES AND EXPENSES:
Cost of sales and operating expenses
(including purchases of $2,450,149, $2,103,726,
$6,680,122 and $4,989,436 from affiliates) 6,267,004 5,298,606 18,284,027 13,694,391
Selling, general and administrative expenses 80,788 67,192 218,115 218,518
Interest expense, excluding capital lease 31,264 17,188 87,124 50,358
Capital lease interest charge 1,011 1,615 3,806 5,402
---------- ---------- ----------- -----------
Total cost of sales and expenses 6,380,067 5,384,601 18,593,072 13,968,669
---------- ---------- ----------- -----------
INCOME BEFORE INCOME TAXES 160,733 88,936 549,045 215,035
INCOME TAXES 57,864 32,016 197,656 77,412
---------- ---------- ----------- -----------
NET INCOME 102,869 56,920 351,389 137,623
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OTHER COMPREHENSIVE (LOSS) INCOME:
Cash flow hedges:
Reclassification adjustment for derivative losses included in net
income, net of related income taxes of $39, $43, $127, and $130 70 77 225 232
Foreign currency translation (loss) gain, net of related income taxes
of $(83), $(86), $591 and $(86) (147) (154) 1,050 (154)
---------- ---------- ----------- -----------
OTHER COMPREHENSIVE (LOSS) INCOME (77) (77) 1,275 78
---------- ---------- ----------- -----------
COMPREHENSIVE INCOME $ 102,792 $ 56,843 $ 352,664 $ 137,701
========== ========== =========== ===========
See notes to condensed consolidated financial statements.
3
CITGO PETROLEUM CORPORATION
CONDENSED CONSOLIDATED STATEMENT OF SHAREHOLDER'S EQUITY (UNAUDITED)
(DOLLARS AND SHARES IN THOUSANDS)
ACCUMULATED
OTHER
COMMON STOCK ADDITIONAL RETAINED COMPREHENSIVE
SHARES AMOUNT CAPITAL EARNINGS (LOSS) INCOME TOTAL
------ ------ ------- -------- ------------- -----
BALANCE, DECEMBER 31, 2002 1 $ 1 $1,659,698 $ 925,114 $ (25,655) $2,559,158
Net income - - - 351,389 - 351,389
Other comprehensive income - - - - 1,275 1,275
Dividends paid - - - (500,000) - (500,000)
---------- ---------- ---------- ---------- ---------- ----------
BALANCE, SEPTEMBER 30, 2003 1 $ 1 $1,659,698 $ 776,503 $ (24,380) $2,411,822
========== ========== ========== ========== ========== ==========
See notes to condensed consolidated financial statements.
4
CITGO PETROLEUM CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)
(DOLLARS IN THOUSANDS)
NINE MONTHS
ENDED SEPTEMBER 30,
--------------------------
2003 2002
---- ----
CASH FLOWS FROM OPERATING ACTIVITIES
Net income $ 351,389 $ 137,623
Depreciation and amortization 245,397 220,983
Other adjustments to reconcile net income to
net cash provided by operating activities 180,203 55,083
Changes in operating assets and liabilities 69,373 68,713
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Net cash provided by operating activities 846,362 482,402
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CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures (315,105) (478,053)
Proceeds from sales of property, plant and equipment 3,845 718
Increase in restricted cash (1,162) (33,507)
Investments in LYONDELL-CITGO Refining LP (17,083) (28,700)
Investments in and advances to other affiliates (2,537) (19,237)
---------- ----------
Net cash used in investing activities (332,042) (558,779)
---------- ----------
CASH FLOWS FROM FINANCING ACTIVITIES:
Net proceeds from short-term bank loans - 119,000
Net repayments of revolving bank loans (279,300) (154,000)
(Payments on) proceeds from loans from affiliates (39,000) 37,000
Proceeds from senior notes due 2011 546,590 -
Proceeds from senior secured term loan 200,000 -
(Payments on) proceeds from tax-exempt bonds (126,050) 62,501
Payments on taxable bonds (90,000) (25,000)
Payments of capital lease obligations (11,860) (9,901)
Payments on master shelf agreement senior notes (50,000) (25,000)
Repurchase of senior notes due 2006 (47,500) -
Repayments of other debt - (8,312)
Dividend paid (500,000) -
Debt issuance costs (19,136) -
---------- ----------
Net cash used in financing activities (416,256) (3,712)
---------- ----------
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 98,064 (80,089)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD 33,025 104,362
---------- ----------
CASH AND CASH EQUIVALENTS, END OF PERIOD $ 131,089 $ 24,273
========== ==========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest, net of amounts capitalized $ 66,578 $ 48,077
========== ==========
Income taxes (net of refunds of $45,000 and $51,381) $ 45,305 $ (45,293)
========== ==========
See notes to condensed consolidated financial statements.
5
CITGO PETROLEUM CORPORATION
NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
THREE-MONTH AND NINE-MONTH PERIODS ENDED SEPTEMBER 30, 2003 AND 2002
1. BASIS OF PRESENTATION
The financial information for CITGO Petroleum Corporation ("CITGO" or "the
Company") subsequent to December 31, 2002 and with respect to the interim
three-month and nine-month periods ended September 30, 2003 and 2002 is
unaudited. In management's opinion, such interim information contains all
adjustments, consisting only of normal recurring adjustments, necessary for
a fair presentation of the results of such periods. The results of
operations for the nine-month periods ended September 30, 2003 and 2002 are
not necessarily indicative of the results to be expected for the full year.
Reference is made to CITGO's Annual Report for the fiscal year ended
December 31, 2002 on Form 10-K/A, dated September 8, 2003, for additional
information.
2. NEW ACCOUNTING PRONOUNCEMENTS
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 at December
31, 2004 to variable interest entities in which a nonpublic enterprise, as
defined, holds a variable interest that it acquired before February 1,
2003. 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. CITGO, which meets the definition of a nonpublic enterprise in
FIN 46, expects that the application of FIN 46 at December 31, 2004 to
variable interest entities in which it acquired an interest before February
1, 2003 will not have a material impact on its financial position or
results of operations.
CITGO holds a 49.5% partnership interest in Nelson Industrial Steam Company
("NISCO"), a variable interest entity. NISCO operates a qualified
cogeneration facility in Louisiana. NISCO had total assets of approximately
$179 million at December 31, 2002 and revenue of approximately $72 million
for the year ended December 31, 2002. CITGO, along with certain other
partners, indirectly purchases electricity produced by NISCO. In addition
to its partnership interest, CITGO provides a limited guarantee on behalf
of NISCO. See Note 8 for CITGO's estimate of its maximum exposure to loss
as a result of its involvement with NISCO.
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
6
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 of potential settlement dates and estimated amounts of costs to be
incurred. Accordingly, the adoption of SFAS No. 143 did not impact the
Company's 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. The changes in principle
effective with the adoption of SFAS No. 149 did not have a material effect
on the Company's statements of financial position and results of operation.
3. ACCOUNTS RECEIVABLE
On February 28, 2003, the Company established a new accounts receivable
sales facility. This facility allows for the non-recourse sale of an
interest in trade accounts receivable meeting specified requirements to
independent third parties. A maximum of $200 million in accounts receivable
may be sold at any one time. At September 30, 2003, no accounts receivable
sold through this facility remained outstanding.
4. INVENTORIES
Inventories, primarily at LIFO, consist of the following:
SEPTEMBER 30,
2003 DECEMBER 31,
(UNAUDITED) 2002
------------ ------------
(000S OMITTED)
Refined products $ 582,799 $ 781,495
Crude oil 291,491 221,422
Materials and supplies 87,816 87,998
---------- ----------
$ 962,106 $1,090,915
========== ==========
5. RESTRICTED CASH
Restricted cash of approximately $25 million at September 30, 2003 is
related to tax-exempt industrial revenue bonds and a product sales and
option agreement.
CITGO issued $30 million of tax-exempt environmental facilities revenue
bonds in June 2002 and $39 million in May 2003. The proceeds from these
bonds will be used for spending on qualified projects at the Lemont and
Corpus Christi refineries. Restricted cash of approximately $14 million at
September 30, 2003 represents highly liquid investments held in trust
accounts in accordance with these bond agreements. Funds
7
may be released solely to finance the qualified capital expenditures as
defined in the related bond agreements.
Restricted cash of approximately $11 million at September 30, 2003 relates
to a product sales and option agreement and represents highly liquid
investments held in accordance with a contract related to that product
sales and option agreement.
6. LONG-TERM DEBT AND FINANCING ARRANGEMENTS
Long-term debt consists of the following:
SEPTEMBER 30,
2003 DECEMBER 31,
(UNAUDITED) 2002
------------- ------------
(000S OMITTED)
Revolving bank loans $ - $ 279,300
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% 149,941 199,898
Senior Notes, $550 million face amount, due 2011 with
interest rate of 11-3/8% 546,841 -
Private Placement Senior Notes, due 2003 to 2006 with
interest rate of 9.30% 45,455 45,455
Master Shelf Agreement Senior Notes, due 2003 to
2009 with interest rates from 7.17% to 8.94% 185,000 235,000
Tax Exempt Bonds, due 2004 to 2033 with variable
and fixed interest rates 299,826 425,872
Taxable Bonds, due 2026 to 2028 with variable interest rates 25,000 115,000
--------- ----------
1,452,063 1,300,525
Current portion of long-term debt (31,364) (190,664)
--------- ----------
$1,420,699 $1,109,861
========== ==========
CITGO's revolving bank loan agreements with various banks consist of (i) a
$260 million, three-year, revolving bank facility, maturing in December
2005; and (ii) a $260 million, 364-day, revolving bank facility, maturing
in December 2003. CITGO does not intend to replace the $260 million,
364-day, revolving bank facility when it matures.
On May 15, 2003, CITGO issued $39 million of tax-exempt revenue bonds due
2008. The proceeds of those bonds will be used for spending on qualified
projects at the Corpus Christi refinery.
On February 27, 2003, CITGO closed on a three-year $200 million, senior
secured term loan with a variable interest rate. The loan is secured by a
pledge of CITGO's 15.8 percent equity interest in Colonial Pipeline and 6.8
percent equity interest in Explorer Pipeline.
8
On February 27, 2003 CITGO issued $550 million aggregate principal amount
of 11-3/8% unsecured senior notes due February 1, 2011. In connection with
this debt issuance, CITGO redeemed $50 million principal amount of its
7-7/8% senior notes due 2006.
The taxable and tax-exempt bonds are supported by letters of credit. CITGO
repurchased $90 million of taxable bonds and $165 million of tax-exempt
bonds due to the non-renewal of these letters of credit in the nine-month
period ending September 30, 2003. We will seek to reissue these bonds, with
replacement letters of credit in support or, alternatively, we will seek to
replace these bonds with new bonds that will not require letter of credit
support.
Our various debt instruments require maintenance of a specified minimum net
worth and impose restrictions on our ability to: incur additional debt
unless we meet specified interest coverage and debt to capitalization
ratios; place liens on our property, subject to specified exceptions; sell
assets, subject to specified exceptions; make restricted payments,
including dividends, repurchases of capital stock and specified
investments; and merge, consolidate or transfer assets. CITGO is in
compliance with its covenants under its debt financing arrangements at
September 30, 2003.
7. INVESTMENT IN LYONDELL-CITGO REFINING LP
LYONDELL-CITGO Refining LP ("LYONDELL-CITGO") owns and operates a 265
thousand barrels per day 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 Petroleos de
Venezuela, S.A. ("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.
From February 2001 through March 2003 PDVSA, pursuant to its contractual
rights, declared force majeure and reduced deliveries of crude oil to
LYONDELL-CITGO. This action required LYONDELL-CITGO to obtain replacement
crude oil supplies, 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 and the force
majeure was lifted March 6, 2003.
CITGO has a note receivable from LYONDELL-CITGO of approximately $35
million at September 30, 2003 and December 31, 2002. The note bears
interest at 1.95% at September 30, 2003. Principal and interest are due in
December 2004. Accordingly, this note and the related accrued interest is
included in the balance sheet caption other assets in the accompanying
consolidated balance sheets.
9
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 differ from
participation interests. Cash distributions are allocated to the Owners
based on participation interest. Information on CITGO's investment in
LYONDELL-CITGO follows:
(000s omitted)
September 30, December 31,
2003 2002
-------------- ------------
(Unaudited)
Carrying value of investment $ 441,010 $ 518,279
Notes receivable 35,278 35,278
Participation interest 41% 41%
Summary of LYONDELL-CITGO's financial position:
Current assets $ 246,000 $ 357,000
Non current assets 1,328,000 1,400,000
Current liabilities:
Distributions payable to partners 8,000 181,000
Current portion of long-term debt 450,000 -
Other 313,000 333,000
Noncurrent liabilities (including long-term debt of $0 at
September 30, 2003 and $450,000 at December 31, 2002) 380,000 840,000
Partners' capital 423,000 403,000
Nine Months Ended September 30,
-------------------------------
2003 2002
------------ -------------
(Unaudited)
Equity in net income $ 56,552 $ 56,127
Cash distribution received 150,904 80,137
Summary of LYONDELL-CITGO's operating results:
Revenue $3,117,794 $2,435,792
Gross profit 224,145 216,499
Net income 155,360 153,969
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 mature in June 2004 and are shown above in current
liabilities.
10
8. 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.
In September 2002, a Texas court ordered the Company 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 the Company's Corpus
Christi, Texas refinery. CITGO has appealed the ruling to the Texas Court
of Appeals.
CITGO is a defendant in a number of state lawsuits alleging contamination
of private and public water supplies by methyl tertiary butyl ether
("MTBE"), a component of gasoline. In general, the plaintiffs claim that
MTBE renders the water not potable. In addition to compensatory and
punitive damages, plaintiffs seek testing and monitoring, remediation
and/or restoration of groundwater and drinking water sources, and other
equitable relief.
Pending Litigation
- New York: Four actions are currently pending against the Company, and
others, in New York state courts. Two have been filed by individual
property owners, one has been filed by a public water supplier, and one is
a purported class action on behalf of private well owners in two New York
communities. The Company has moved to dismiss each of the cases.
- Illinois: The Company is defending two actions pending in Illinois state
court (Madison County). One is a purported class action on behalf of
Illinois private well owners. The other case was filed by the Village of
East Alton alleging contamination of its public water supplies. Both cases
are scheduled for trial in the fall of 2004.
New developments
The Company has learned that approximately 50 new MTBE lawsuits have been
filed in state courts in Illinois, New York, New Hampshire, Connecticut,
Massachusetts, Florida, Iowa, Indiana and California since September 30,
2003. To date, CITGO has been served in approximately ten of these cases,
in Connecticut, New Hampshire, Illinois, Indiana and New York. The
Connecticut, Indiana and New York lawsuits were filed on behalf of public
water suppliers and allege MTBE contamination of public drinking water
sources. The Illinois lawsuit is a putative nationwide class action on
behalf of all public water suppliers and alleges MTBE contamination of
public drinking water sources. The New Hampshire case was filed by the New
Hampshire State Attorney General to protect the state's water resources.
The lawsuit seeks restoration and remediation, monitoring and testing of
all public and private water supplies in the state, as well as compensatory
and punitive damages, and fines.
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.
11
CITGO has 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 CITGO 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 CITGO owned or operated the premises at
issue. In some of these cases, CITGO is indemnified by or has the right to
seek indemnification for losses and expenses that CITGO may incur from
prior owners of the refineries or employers of the claimants. In other
cases, CITGO's involvement arises not from having been sued directly but
because prior owners of the CITGO refineries have asserted indemnification
rights against CITGO. The Company does not believe that the resolution of
these cases will have a material adverse effect on its financial condition
or results of operations.
At September 30, 2003, CITGO's balance sheet included an accrual for
lawsuits and claims of $25 million compared with $23 million at December
31, 2002. The increase in the accrual is due primarily to a revision in the
estimated cost to CITGO in resolving various lawsuits and claims. In
addition, CITGO estimates that an additional loss of $3 million is
reasonably possible in connection with such lawsuits and claims.
ENVIRONMENTAL COMPLIANCE AND REMEDIATION - CITGO is 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 programs. CITGO is required to
obtain permits under all of these programs and believes it is in material
compliance with the terms of these permits. CITGO does not have any
material Comprehensive Environmental Response, Compensation, and Liability
Act ("CERCLA") liability because the former owners of many of CITGO's
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 sulphur 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 NSR
provisions of the CAA have created uncertainty about the extent to which
additional capital and operating expenditures will be required and
administrative penalties imposed.
In addition, CITGO is subject to various other federal, state and local
environmental laws and regulations that 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. See "Factors Affecting
Forward Looking Statements."
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.
12
In 1992, the Company reached an agreement with the Louisiana Department of
Environmental Quality ("LDEQ") to cease usage of certain surface
impoundments at its Lake Charles refinery by 1994. A mutually acceptable
closure plan was filed with the LDEQ in 1993. The Company 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, CITGO
presented a proposal to the LDEQ revising the 1993 closure plan. In 1998
and 2000, CITGO 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. CITGO has incurred remediation costs to date related to these
surface impoundments of approximately $45 million. Based on currently
available information and proposed remedial approach, CITGO currently
anticipates closure and post-closure costs related to these surface
impoundments and related solid waste management units to range from $36
million to $41 million.
The Texas Commission on Environmental Quality ("TCEQ") and CITGO have
reached agreement in principle on the general terms of a settlement
agreement that is intended to resolve all outstanding enforcement issues
between the Company and the TCEQ related to the Corpus Christi Refinery.
This settlement includes all issues which have been the subject of prior,
pending or threatened enforcement proceedings by the TCEQ. Although the
complete terms of the settlement have not yet been finalized in an Agreed
Order between the TCEQ and CITGO, CITGO estimates that the capital
expenditures and penalties that will be required under the settlement will
range up to an aggregate of $21 million, to be incurred over a period of
years.
In June 1999, CITGO and numerous other industrial companies received notice
from the U.S. EPA that the U.S. EPA believed that CITGO 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 the CERCLA. The U.S. EPA
made a demand for payment of its past investigation costs from CITGO 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. CITGO and other PRPs may be potentially responsible for
the costs of the RI/FS, subsequent remedial actions and natural resource
damages. Although CITGO is still reviewing the recent remedial
investigation phase of the report and its implications, CITGO 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 the Company disagrees with many of the U.S. EPA's earlier
allegations and conclusions, the Company is in discussions with the LDEQ on
issues relative to its operations adjacent to the Bayou D'Inde tributary
section of the Calcasieu Estuary and separately on issues relative to its
refinery operations on other sections of the Estuary. If necessary, the
Company still 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 CAA. 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 CAA. The NOVs followed inspections and formal
information requests regarding the Company's Lake Charles, Louisiana,
Corpus Christi, Texas and Lemont, Illinois refineries. Since mid-2002,
CITGO has 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 principal, 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, CITGO estimates that the capital costs of a settlement with
the United States could be approximately $200 million. Any such capital
costs would be incurred
13
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. The
Company 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, it estimates 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 the
Company's Lemont, Illinois refinery. CITGO is in settlement discussions
with the U.S. EPA. CITGO 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 various violations of the Louisiana
air quality regulations at CITGO's Lake Charles, Louisiana refinery during
2001. The majority of the alleged violations related to the leak detection
and repair program. Current settlement discussions with the LDEQ are
reasonably expected to include a penalty in excess of $100,000.
At September 30, 2003, CITGO's balance sheet included an environmental
accrual of $63 million compared with $68 million at December 31, 2002. The
decline in the accrual is due primarily to a revision of the Company's
estimated share of costs related to a site which is still under
investigation by the U.S. EPA. In addition, CITGO estimates that an
additional loss of $15 million is reasonably possible in connection with
environmental matters.
Various regulatory authorities have the right to conduct, and from time to
time do conduct, environmental compliance audits of CITGO 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 actions and/or penalties in an
administrative or judicial proceeding. Based upon current information,
CITGO 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 CITGO believe that any such
audit or their findings will have a material adverse effect on its future
business and operating results, other than matters described above.
Conditions which require additional expenditures may exist with respect to
the Company's various sites including, but not limited to, its operating
refinery complexes, former refinery sites, service stations and crude oil
and petroleum product storage terminals. Based on currently available
information, CITGO cannot determine the amount of any such future
expenditures.
DERIVATIVE COMMODITY AND FINANCIAL INSTRUMENTS - As of September 30, 2003
CITGO'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 September 30, 2003,
the balance sheet captions prepaid expenses and other current assets and
other current liabilities include $21 million and $13 million,
respectively, related to the fair values of open commodity derivatives.
CITGO has also entered into various interest rate swaps to manage the
Company's risk related to interest rate changes on its debt. The fair value
of the interest rate swap agreements in place at September 30, 2003, based
on the estimated amount that the Company 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, the offset of which is recorded in the
balance sheet caption other current liabilities. In connection with the
determination of fair
14
market value, the Company considered the creditworthiness of the
counterparties, but no adjustment was determined to be necessary as a
result.
GUARANTEES - As of September 30, 2003, 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, customer debt related to the
acquisition of marketing equipment and financing debt incurred by an equity
investment as shown in the following table:
EXPIRATION
DATE
(000s omitted) ------------
Letters of credit $ 32,981 2003 - 2004
Bank debt
Affiliate 10,000 2003 - 2004
Equity investment 5,500 2004
Customers 2,393 2005 - 2009
Financing debt
Customer equipment acquisition 1,306 2003 - 2007
Equity investment - NISCO 11,894 2008
--------
Total $ 64,074
========
In each case, if the debtor fails to meet its obligation, CITGO could be
obligated to make the required payment. 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. ("PDV Holding"), 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. In the event of debtor default on financing debt incurred by
an equity investee, CITGO has no recourse.
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.
15
9. RELATED PARTY TRANSACTIONS
CITGO 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.
These crude supply agreements contain force majeure provisions that excuse
the performance by either party of its obligations under the agreement
under specified circumstances. PDVSA invoked the force majeure provisions
and reduced the volume of crude oil supplied under the contracts in April
1998, from February 1999 through October 2000 and from February 2001
through March 2003. As a result of these declarations of force majeure, the
Company was required to obtain crude oil from alternative sources, which
resulted in increased volatility in its operating margins. The Company was
notified that effective March 6, 2003, PDVSA ended its most recent
declaration of force majeure under the crude oil supply agreements.
In August 2002, three affiliates entered into agreements to advance excess
cash to the Company 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. 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. At September 30, 2003, there was no outstanding balance on
these notes.
10. INSURANCE RECOVERIES
On August 14, 2001, a fire occurred at the crude oil distillation unit of
the Lemont refinery. 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. 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 three-month periods ended September 30, 2003 and 2002, the Company
recorded $2 million and $46 million, respectively, of insurance recoveries
primarily related to these fires. During the nine-month periods ended
September 30, 2003 and 2002, the Company recorded $146 million and $257
million, respectively, of insurance recoveries primarily related to these
fires. The Company received cash proceeds of $20 million and $49 million
during the three-month periods ended September 30, 2003 and 2002. The
Company received cash proceeds of $146 million and $292 million during the
nine-month periods ended September 30, 2003 and 2002. In July 2003, the
Company received the final payment related to the Lemont fire.
16
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
OVERVIEW
This discussion of our financial condition and results of operations should
be read in conjunction with our unaudited condensed consolidated financial
statements included elsewhere in this report. We also direct your attention to
our Form 10-K annual report for our fiscal year ended December 31, 2002, for
additional information and a description of critical accounting policies and
factors that may cause substantial fluctuations in our earnings and cash flows.
We generated net income of $102.9 million on total revenue of $6.5 billion
in the quarter ended September 30, 2003 compared to a net income of $56.9
million on total revenue of $5.5 billion for the same period last year. We
generated net income of $351.4 million on revenue of $19.1 billion in the nine
months ended September 30, 2003 compared to net income of $137.6 million on
total revenue of $14.2 billion for the same period last year. (See "Gross
margin").
RESULTS OF OPERATIONS
The following table summarizes the sources of our sales revenues and sales
volumes for the three-month and nine-month periods ended September 30, 2003 and
2002:
CITGO SALES REVENUES AND VOLUMES
THREE MONTHS NINE MONTHS THREE MONTHS NINE MONTHS
ENDED SEPTEMBER 30 ENDED SEPTEMBER 30 ENDED SEPTEMBER 30 ENDED SEPTEMBER 30
------------------ ------------------ ------------------ ------------------
2003 2002 2003 2002 2003 2002 2003 2002
---- ---- ---- ---- ---- ---- ---- ----
($ in millions) (gallons in millions)
Gasoline $ 3,831 $ 3,363 $10,727 $ 8,432 3,918 4,056 11,272 11,014
Jet fuel 513 359 1,451 991 640 479 1,734 1,483
Diesel/#2 fuel 1,173 899 4,043 2,439 1,479 1,232 4,762 3,724
Asphalt 238 245 514 468 331 353 689 707
Petrochemicals and industrial products 570 379 1,653 1,053 662 555 1,915 1,593
Lubricants and waxes 157 143 448 422 67 67 194 195
----------------- ----------------- ----------------- -----------------
Total refined product sales 6,482 5,388 18,836 13,805 7,097 6,742 20,566 18,716
Other sales and adjustments 20 23 63 70
----------------- ----------------- ----------------- -----------------
Total sales $ 6,502 $ 5,411 $18,899 $13,875 7,097 6,742 20,566 18,716
================= ================= ================= =================
17
The following table summarizes our cost of sales and operating expenses for
the three-month and nine-month periods ended September 30, 2003 and 2002:
CITGO COST OF SALES AND OPERATING EXPENSES
THREE MONTHS NINE MONTHS
ENDED SEPTEMBER 30, ENDED SEPTEMBER 30,
--------------------- ---------------------
2003 2002 2003 2002
------- ------- ------- -------
($ in millions)
Crude oil $ 1,724 $ 1,641 $ 5,110 $ 3,827
Refined products 3,577 2,876 10,409 7,556
Intermediate feedstocks 481 352 1,420 1,104
Refining and manufacturing costs 323 314 963 900
Other operating costs, expenses and inventory changes 162 116 382 307
------- ------- ------- -------
Total cost of sales and operating expenses $ 6,267 $ 5,299 $18,284 $13,694
======= ======= ======= =======
Sales revenues and volumes. Sales increased $1.1 billion, or approximately
20%, in the three-month period ended September 30, 2003 as compared to the same
period in 2002. This increase was due to an increase in average sales price of
14% and an increase in sales volume of 5%. Sales increased $5.0 billion, or
approximately 36%, in the nine-month period ended September 30, 2003 compared to
the same period in 2002. This increase was due to an increase in average sales
price of 24% and an increase in refined product sales volume of 10%. (See CITGO
Sales Revenues and Volumes table above.)
Equity in earnings of affiliates. Equity in earnings of affiliates
increased by $7 million for the three-month period ended September 30, 2003 and
increased $3 million for the nine-month period ended September 30, 2003 as
compared to the same period in 2002. The increase in the three-month period was
due primarily to an increase in the earnings of LYONDELL-CITGO, our share of
which increased $8 million. The increase in LYONDELL-CITGO'S earnings was
primarily due to improved refinery margins during the third quarter of 2003 as
compared to the same period in 2002.
Insurance recoveries. We recorded insurance recoveries of $2 million in the
three months ended September 30, 2003 and $146 million in the nine months ended
September 30, 2003. The recoveries for the nine-month period related 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. We do not expect any additional insurance recoveries related to the
Lemont fire.
Cost of sales and operating expenses. Cost of sales and operating expenses
increased by $968 million or 18%, in the quarter ended September 30, 2003 as
compared to the same period in 2002. Cost of sales and operating expenses
increased by $4.6 billion or 34%, in the nine months ended September 30, 2003 as
compared to the same period in 2002. (See CITGO 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. Refined
product purchases represented 57% and 54% of total cost of sales and operating
expenses for the third quarter of 2003 and 2002, respectively and 57% and 55%
for the nine-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
18
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 "Factors Affecting Forward Looking Statements".)
Gross margin. The gross margin for the three-month period ended September
30, 2003 was approximately 3.3 cents per gallon, compared to approximately 1.7
cents per gallon for the same period in 2002. The gross margin for the
nine-month period ended September 30, 2003 was approximately 3.0 cents per
gallon, compared to less than one cent per gallon for the same period in 2002.
The revenue per gallon component in the three-month period ended September 30,
2003 increased approximately 14% and the cost per gallon component increased
approximately 12%. As a result, the gross margin increased approximately 1.7
cents on a per gallon basis in the quarter ended September 30, 2003 compared to
the same period in 2002. In the nine-month period ended September 30, 2003, the
revenue per gallon component increased approximately 24% and the cost per gallon
component increased approximately 22%. As a result, the gross margin increased
approximately 2.0 cents on a per gallon basis in the nine months ended September
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
nine months 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 increased 20% from $67 million in the third quarter of
2002 to $81 million in the third quarter of 2003. Selling, general and
administrative expenses remained relatively flat at $219 million in the first
nine months of 2002 compared to $218 million in the same period in 2003. The
increase in selling, general and administrative expenses during the quarter
ended September 30, 2003 is primarily related to an increase in labor burden,
incentive compensation, and expenses related to an early retirement program.
Interest expense. Interest expense increased by $13 million in the
three-month period ended September 30, 2003 and increased $35 million in the
nine-month period ended September 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.
LIQUIDITY AND CAPITAL RESOURCES
Consolidated net cash provided by operating activities totaled
approximately $846 million for the nine-month period ended September 30, 2003.
Operating cash flows were derived primarily from net income of $351 million,
depreciation and amortization of $245 million, distributions in excess of equity
in earnings of affiliates of $100 million, increase in deferred taxes of $54
million, and changes in operating assets and liabilities of $69 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.
19
Net cash used in investing activities in the nine month period ended
September 30, 2003 totaled $332 million consisting primarily of capital
expenditures of $315 million. These capital expenditures consisted of:
Three Nine
Months Months
--------- ---------
Ended September 30, 2003
------------------------
($ in millions)
Regulatory requirements $ 75 $ 198
Maintenance capital projects 10 42
Strategic capital expenditures 21 75
--------- ---------
Total capital expenditures $ 106 $ 315
========= =========
Net cash used by financing activities totaled $416 million for the
nine-month period ended September 30, 2003, consisting primarily of the payment
of a $500 million dividend payment to PDV America, the repayments of $279
million on revolving bank loans; the repurchase of $126 million of tax-exempt
bonds; the repurchase of $90 million of taxable bonds; the repurchase of $50
million of our 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 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 loan, and
the repurchase of taxable and tax-exempt bonds; and capital lease payments of
$12 million. These payments were offset by proceeds from our senior secured term
loan of $200 million and the proceeds from our 11-3/8% senior notes due in 2011
of $547 million.
As of September 30, 2003, capital resources available to us included cash
on hand totaling $131 million generated by operations and other sources, and
available borrowing capacity under our committed bank facilities of $517
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 "Factors Affecting Forward Looking
Statements".)
Our various debt instruments require maintenance of a specified minimum net
worth and impose restrictions on our ability to:
- incur additional debt unless we meet specified interest coverage and debt
to capitalization ratios;
- place liens on our property, subject to specified exceptions;
- sell assets, subject to specified exceptions;
- make restricted payments, including dividends, repurchases of capital stock
and specified investments; and
- merge, consolidate or transfer assets.
We are in compliance with our covenants under our debt financing
arrangements at September 30, 2003.
20
Upon the occurrence of a change of control of our Company, as defined in
the Indenture governing our 11-3/8% senior notes due 2011, the holders of those
notes have the right to require us to repurchase them at a price equal to 101%
of the principal amount plus accrued interest. In addition, our bank credit
agreements provide that, unless lenders holding two-thirds of the commitments
thereunder otherwise agree, a change in control of our Company, as defined in
those agreements, will constitute a default under those credit agreements.
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 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. 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 in 2004 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 have outstanding letters of credit that support taxable and tax-exempt
bonds that were issued previously for our benefit. Through September 30, 2003,
we repurchased $90 million of taxable bonds and $165 million of tax-exempt bonds
due to the non-renewal of these letters of credit. We will seek to reissue these
bonds, with replacement letters of credit in support or, alternatively, we will
seek to replace these bonds with new bonds that will not require letter of
credit support. As of November 1, 2003, we have an additional $182 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 September 30, 2004.
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, $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 September 30, 2003, there was no outstanding
balance on these notes.
Our senior unsecured debt ratings, 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.
21
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.
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 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.
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.
NEW ACCOUNTING STANDARDS
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 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 at December 31, 2004 to variable interest entities in which a nonpublic
enterprise, as defined, holds a variable interest that it acquired before
February 1, 2003. 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
meet the definition of a nonpublic enterprise and expect that the application of
FIN 46 at December 31, 2004 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.
We hold a 49.5% partnership interest in NISCO, a variable interest entity.
NICSO operates a qualified cogeneration facility in Louisiana. NISCO had total
assets of approximately $179 million at December 31, 2002 and revenue of
approximately $72 million for the year ended December 31, 2002. We, along with
certain other
22
partners, indirectly purchase electricity produced by NISCO. In addition to our
partnership interest, we provide a limited guarantee on behalf of NISCO. See
Note 8 for our estimate of our maximum exposure to loss as a result of our
involvement with NISCO.
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. The changes in principle effective with the adoption of SFAS No.
149 did not have a material effect on our statements of financial position and
results of operation.
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. Currently, adoption is not expected to be required before fiscal years
beginning after December 15, 2004. At September 30, 2003, we have included
turnaround costs of $172 million 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.
23
ITEM 3. 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 September 30, 2003, 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
September 30, 2003 aggregate commodity derivative positions entered into for
price risk management purposes totaled 3.2 million barrels and 1.0 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 $25 million or
greater. At September 30, 2003, none of our commodity derivatives were accounted
for as hedges.
NON TRADING COMMODITY DERIVATIVES
OPEN POSITIONS AT SEPTEMBER 30, 2003
MATURITY NUMBER OF CONTRACT MARKET
COMMODITY DERIVATIVE DATE CONTRACTS VALUE VALUE (4)
--------- ---------- ---- ------------ -------- ---------
LONG/(SHORT) ASSET/(LIABILITY)
------------ --------------------
($ in millions)
No Lead Gasoline (1) Futures Purchased 2003 452 $ 14.8 $ 15.3
Futures Sold 2003 (450) $ (14.7) $ (15.2)
Forward Purchase Contracts 2003 6,745 $ 223.8 $ 223.1
Forward Sales Contracts 2003 (5,203) $ (174.3) $ (171.1)
Distillates (1) Futures Purchased 2003 1,551 $ 49.9 $ 51.8
Futures Purchased 2004 1,457 $ 45.5 $ 47.3
Futures Sold 2003 (75) $ (2.5) $ (2.5)
OTC Call Options Purchased 2003 12 $ - $ -
OTC Put Options Purchased 2003 12 $ - $ 0.1
OTC Call Options Sold 2003 (12) $ - $ (0.1)
OTC Put Options Sold 2003 (12) $ - $ -
OTC Swaps (Pay Fixed/Receive Float)(3) 2003 3 $ - $ -
Forward Purchase Contracts 2003 675 $ 21.2 $ 21.8
Forward Sale Contracts 2003 (965) $ (31.4) $ (31.9)
Crude Oil (1) OTC Swaps (Pay Fixed/Receive Float)(3) 2003 900 $ - $ 0.1
OTC Swaps (Pay Float/Receive Fixed)(3) 2003 (1,100) $ - $ 0.2
Forward Purchase Contracts 2003 1,550 $ 40.2 $ 43.0
Forward Sale Contracts 2003 (1,032) $ (28.3) $ (29.9)
Natural Gas (2) Listed Call Options Purchased 2003 100 $ - $ -
Listed Call Options Sold 2003 (100) $ - $ -
- --------------------------------
(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.
24
NON TRADING COMMODITY DERIVATIVES
OPEN POSITIONS AT SEPTEMBER 30, 2002
MATURITY NUMBER OF CONTRACT MARKET
COMMODITY DERIVATIVE DATE CONTRACTS VALUE VALUE (4)
--------- ---------- ---- ---------- -------- ---------
LONG/(SHORT) ASSET/(LIABILITY)
------------ --------------------
($ in millions)
No Lead Gasoline (1) Futures Purchased 2002 50 $ 1.7 $ 1.7
Futures Sold 2002 2,902 $ 99.4 $ 98.1
Forward Purchase Contracts 2002 5,901 $ 194.7 $ 204.6
Forward Sale Contracts 2002 4,765 $ 159.8 $ 164.3
Distillates (1) Futures Purchased 2002 2,253 $ 72.8 $ 76.6
Futures Purchased 2003 646 $ 18.3 $ 20.6
Futures Sold 2002 350 $ 11.8 $ 11.9
Futures Sold 2003 595 $ 18.7 $ 18.5
OTC Options Purchased 2002 66 $ - $ 0.1
OTC Options Sold 2002 66 $ - $ (0.1)
Forward Purchase Contracts 2002 812 $ 26.7 $ 27.3
Forward Sale Contracts 2002 1,255 $ 42.6 $ 42.8
Crude Oil (1) Futures Purchased 2002 2,732 $ 83.0 $ 83.2
Futures Purchased 2003 595 $ 16.5 $ 16.5
Futures Sold 2002 377 $ 10.0 $ 11.3
Futures Sold 2003 475 $ 11.6 $ 13.5
Listed Options Purchased 2002 300 $ - $ -
Listed Options Sold 2002 300 $ - $ -
OTC Swaps (Pay Floating/Receive Fixed)(3) 2002 1,280 $ - $ (0.4)
Forward Purchase Contracts 2002 6,794 $ 178.1 $ 187.0
Forward Sale Contracts 2002 4,149 $ 111.5 $ 116.1
Natural Gas (2) Futures Sold 2002 40 $ 1.6 $ 1.7
Propane (1) OTC Swaps (Pay Floating/Receive Fixed)(3) 2002 300 $ - $ (0.8)
OTC Swaps (Pay Floating/Receive Fixed)(3) 2003 300 $ - $ (0.8)
OTC Swaps (Pay Fixed/Receive Floating)(3) 2002 75 $ - $ 0.3
OTC Swaps (Pay Fixed/Receive Floating)(3) 2003 75 $ - $ 0.3
- --------------------------------
(1) Thousands of barrels
(2) Ten-thousands of mmbtu
(3) Floating price based on market index designated in contract;
fixed price agreed upon at date of contract.
(4) Based on actively quoted prices.
25
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 September 30, 2003 and 2002, 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 SEPTEMBER 30, 2003 AND 2002
NOTIONAL
FIXED PRINCIPAL
VARIABLE RATE INDEX EXPIRATION DATE RATE 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
===
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
September 30, 2003, 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 $3 million, the offset of which is recorded in the
balance sheet caption other current liabilities.
26
For debt obligations, the table below presents principal cash flows and
related weighted average interest rates by expected maturity dates. Weighted
average variable rates are based on implied forward rates in the yield curve at
the reporting date.
DEBT OBLIGATIONS
AT SEPTEMBER 30, 2003
EXPECTED
FIXED AVERAGE FIXED VARIABLE AVERAGE VARIABLE
EXPECTED MATURITIES RATE DEBT INTEREST RATE RATE DEBT INTEREST RATE
- ------------------- --------- ------------- --------- -------------
($ in millions) ($ in millions)
2003 $ 11 9.30% $ - -
2004 31 8.02% - -
2005 11 9.30% - -
2006 201 8.10% 200 7.41%
2007 50 8.94% - -
Thereafter 770 10.30% 178 9.39%
------ ------ ---- -----
Total $1,074 9.74% $378 8.34%
====== ====== ==== =====
Fair Value $1,166 $378
====== ====
DEBT OBLIGATIONS
AT SEPTEMBER 30, 2002
EXPECTED
FIXED AVERAGE FIXED VARIABLE AVERAGE VARIABLE
EXPECTED MATURITIES RATE DEBT INTEREST RATE RATE DEBT INTEREST RATE
- ------------------- --------- ------------- --------- -------------
($ in millions) ($ in millions)
2002 $ 11 9.30% $ 119 3.07%
2003 61 8.79% 238 3.94%
2004 31 8.02% 16 4.81%
2005 11 9.30% - -
2006 252 8.06% - -
Thereafter 183 7.90% 467 8.24%
----- ----- ----- -----
Total $ 549 8.14% $ 840 6.23%
===== ===== ===== =====
Fair Value $ 580 $ 840
===== =====
27
ITEM 4. CONTROLS AND PROCEDURES
During the third quarter of 2003, the Company's management, including the
principal executive officer and principal financial officer, evaluated the
Company's disclosure controls and procedures related to the recording,
processing, summarization and reporting of information in the Company's periodic
reports that it files with the Securities and Exchange Commission ("SEC"). These
disclosure controls and procedures have been designed to ensure that (a)
material information relating to the Company, including its consolidated
subsidiaries, is made known to the Company's management, including these
officers, by other employees of the Company and its subsidiaries, and (b) this
information is recorded, processed, summarized, evaluated and reported, as
applicable, within the time periods specified in the SEC's rules and forms. Due
to the inherent limitations of control systems, not all misstatements may be
detected. These inherent limitations include the realities that judgments in
decision-making can be faulty and that breakdowns can occur because of simple
error or mistake. Additionally, controls can be circumvented by the individual
acts of some persons, by collusion of two or more people, or by management
override of the control. The Company's controls and procedures can only provide
reasonable, not absolute, assurance that the above objectives have been met.
Also, the Company does not control or manage certain of its unconsolidated
entities and thus, its access and ability to apply procedures to those entities
are more limited than is the case for its consolidated subsidiaries.
As of September 30, 2003, these officers concluded that the Company's
disclosure controls and procedures were effective to accomplish their
objectives.
There have been no significant changes in the Company's internal controls
or in other factors that could significantly affect these controls subsequent to
the date of their evaluation.
28
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
The required information is incorporated by reference into Part II of this
Report from Note 7 of the Notes to the Condensed Consolidated Financial
Statements included in Part I of this Report.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the
Securities Exchange Act of 1934 as to the Quarterly Report on Form
10-Q for the quarterly period ended September 30, 2003 filed by the
following officers:
31.1 Filed by Luis Marin, President and Chief Executive Officer.
31.2 Filed by Eddie R. Humphrey, Chief Financial Officer.
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18
United States Code as to the Quarterly Report on Form 10-Q for the
quarterly period ended September 30, 2003 filed by the following
officers:
32.1 Filed by Luis Marin, President and Chief Executive Officer.
32.2 Filed by Eddie R. Humphrey, Chief Financial Officer.
(b) Reports on Form 8-K:
A report on Form 8-K was filed with the Securities and Exchange Commission
on August 18, 2003. The purpose of this report was to furnish information
included in our press release on earnings for the second quarter of 2003.
A report on Form 8-K/A was filed with the Securities and Exchange
Commission on September 8, 2003 to amend the information in our report on Form
8-K filed May 2, 2003.
A report on Form 8-K was filed with the Securities and Exchange Commission
on October 28, 2003 to furnish information included in our press release of the
same date clarifying certain published reports.
A report on Form 8-K was filed with the Securities and Exchange Commission
on October 31, 2003 to furnish information included in our press release on
earnings for the third quarter of 2003.
29
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
CITGO PETROLEUM CORPORATION
Date: November 10, 2003 /s/ Larry E. Krieg
------------------------------------
Larry E. Krieg
Controller (Chief Accounting Officer)
30
EXHIBIT INDEX
(a) Exhibits
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the
Securities Exchange Act of 1934 as to the Quarterly Report on Form
10-Q for the quarterly period ended September 30, 2003 filed by the
following officers:
31.1 Filed by Luis Marin, President and Chief Executive Officer.
31.2 Filed by Eddie R. Humphrey, Chief Financial Officer.
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18
United States Code as to the Quarterly Report on Form 10-Q for the
quarterly period ended September 30, 2003 filed by the following
officers:
32.1 Filed by Luis Marin, President and Chief Executive Officer.
32.2 Filed by Eddie R. Humphrey, Chief Financial Officer.
31