UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
|
|
|
þ
|
|
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
|
For the quarterly period ended September 30, 2005
OR
|
|
|
o
|
|
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 1-13175
VALERO ENERGY CORPORATION
(Exact name of registrant as specified in its charter)
|
|
|
Delaware
(State or other jurisdiction of
incorporation or organization)
|
|
74-1828067
(I.R.S. Employer
Identification No.)
|
One Valero Way
San Antonio, Texas
(Address of principal executive offices)
78249
(Zip Code)
|
|
|
(210) 345-2000
(Registrants telephone number, including area code)
|
|
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
þ
No
o
Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of
the Exchange Act).
Yes
þ
No
o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the
Exchange Act).
Yes
o
No
þ
The number of shares of the registrants only class of common stock, $0.01 par value, outstanding
as of October 31, 2005 was 309,255,228.
VALERO ENERGY CORPORATION AND SUBSIDIARIES
INDEX
2
PART I FINANCIAL INFORMATION
Item 1. Financial Statements
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(Millions of Dollars, Except Par Value)
|
|
|
|
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
2005
|
|
|
2004
|
|
|
|
(Unaudited)
|
|
|
|
|
|
ASSETS
|
|
|
|
|
|
|
|
|
Current assets:
|
|
|
|
|
|
|
|
|
Cash and temporary cash investments
|
|
$
|
737
|
|
|
$
|
864
|
|
Restricted cash
|
|
|
90
|
|
|
|
24
|
|
Receivables, net
|
|
|
3,553
|
|
|
|
1,839
|
|
Inventories
|
|
|
4,475
|
|
|
|
2,318
|
|
Deferred income taxes
|
|
|
|
|
|
|
175
|
|
Prepaid expenses and other
|
|
|
257
|
|
|
|
44
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
9,112
|
|
|
|
5,264
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, at cost
|
|
|
19,511
|
|
|
|
12,295
|
|
Accumulated depreciation
|
|
|
(2,359
|
)
|
|
|
(1,978
|
)
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
|
17,152
|
|
|
|
10,317
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Intangible assets, net
|
|
|
307
|
|
|
|
311
|
|
Goodwill
|
|
|
4,963
|
|
|
|
2,401
|
|
Investment in Valero L.P.
|
|
|
292
|
|
|
|
265
|
|
Deferred charges and other assets, net
|
|
|
948
|
|
|
|
834
|
|
|
|
|
|
|
|
|
Total assets
|
|
$
|
32,774
|
|
|
$
|
19,392
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
Current liabilities:
|
|
|
|
|
|
|
|
|
Current portion of long-term debt and capital lease obligations
|
|
$
|
269
|
|
|
$
|
412
|
|
Accounts payable
|
|
|
5,969
|
|
|
|
2,963
|
|
Accrued expenses
|
|
|
984
|
|
|
|
519
|
|
Taxes other than income taxes
|
|
|
470
|
|
|
|
480
|
|
Income taxes payable
|
|
|
174
|
|
|
|
160
|
|
Deferred income taxes
|
|
|
121
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
7,987
|
|
|
|
4,534
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term debt and capital lease obligations, less current portion
|
|
|
6,109
|
|
|
|
3,901
|
|
|
|
|
|
|
|
|
Deferred income taxes
|
|
|
3,420
|
|
|
|
2,011
|
|
|
|
|
|
|
|
|
Other long-term liabilities
|
|
|
1,464
|
|
|
|
1,148
|
|
|
|
|
|
|
|
|
Commitments and contingencies (Note 15)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stockholders equity:
|
|
|
|
|
|
|
|
|
Preferred stock, $0.01 par value; 20,000,000 shares authorized;
3,574,257 and 10,000,000 shares issued and outstanding
|
|
|
76
|
|
|
|
208
|
|
Common stock, $0.01 par value; 600,000,000 shares authorized;
310,029,957 and 261,188,614 shares issued
|
|
|
3
|
|
|
|
3
|
|
Additional paid-in capital
|
|
|
8,290
|
|
|
|
4,358
|
|
Treasury stock, at cost; 1,703,939 and 5,712,762 shares
|
|
|
(83
|
)
|
|
|
(199
|
)
|
Retained earnings
|
|
|
5,359
|
|
|
|
3,199
|
|
Accumulated other comprehensive income
|
|
|
149
|
|
|
|
229
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
13,794
|
|
|
|
7,798
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
|
|
$
|
32,774
|
|
|
$
|
19,392
|
|
|
|
|
|
|
|
|
See Condensed Notes to Consolidated Financial Statements.
3
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
(Millions of Dollars, Except per Share Amounts and Supplemental Information)
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2005
|
|
|
2004
|
|
|
2005
|
|
|
2004
|
|
Operating revenues (1) (2)
|
|
$
|
23,283
|
|
|
$
|
14,339
|
|
|
$
|
56,268
|
|
|
$
|
39,228
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales (1)
|
|
|
20,638
|
|
|
|
12,683
|
|
|
|
49,389
|
|
|
|
34,260
|
|
Refining operating expenses
|
|
|
772
|
|
|
|
529
|
|
|
|
1,938
|
|
|
|
1,553
|
|
Retail selling expenses
|
|
|
201
|
|
|
|
177
|
|
|
|
561
|
|
|
|
518
|
|
General and administrative expenses
|
|
|
129
|
|
|
|
87
|
|
|
|
303
|
|
|
|
263
|
|
Depreciation and amortization expense
|
|
|
232
|
|
|
|
164
|
|
|
|
615
|
|
|
|
464
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
21,972
|
|
|
|
13,640
|
|
|
|
52,806
|
|
|
|
37,058
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
|
1,311
|
|
|
|
699
|
|
|
|
3,462
|
|
|
|
2,170
|
|
Equity in earnings of Valero L.P.
|
|
|
13
|
|
|
|
10
|
|
|
|
32
|
|
|
|
29
|
|
Other income (expense), net
|
|
|
11
|
|
|
|
7
|
|
|
|
(4
|
)
|
|
|
4
|
|
Interest and debt expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Incurred
|
|
|
(85
|
)
|
|
|
(73
|
)
|
|
|
(230
|
)
|
|
|
(222
|
)
|
Capitalized
|
|
|
18
|
|
|
|
10
|
|
|
|
39
|
|
|
|
27
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income tax expense
|
|
|
1,268
|
|
|
|
653
|
|
|
|
3,299
|
|
|
|
2,008
|
|
Income tax expense
|
|
|
406
|
|
|
|
219
|
|
|
|
1,056
|
|
|
|
693
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
|
862
|
|
|
|
434
|
|
|
|
2,243
|
|
|
|
1,315
|
|
Preferred stock dividends
|
|
|
4
|
|
|
|
3
|
|
|
|
12
|
|
|
|
9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income applicable to common stock
|
|
$
|
858
|
|
|
$
|
431
|
|
|
$
|
2,231
|
|
|
$
|
1,306
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per common share
|
|
$
|
3.11
|
|
|
$
|
1.69
|
|
|
$
|
8.49
|
|
|
$
|
5.13
|
|
Weighted-average common shares outstanding
(in millions)
|
|
|
276
|
|
|
|
256
|
|
|
|
263
|
|
|
|
255
|
|
Earnings per common share assuming dilution
|
|
$
|
2.94
|
|
|
$
|
1.57
|
|
|
$
|
7.92
|
|
|
$
|
4.78
|
|
Weighted-average common equivalent shares
outstanding (in millions)
|
|
|
294
|
|
|
|
276
|
|
|
|
283
|
|
|
|
275
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Dividends per common share
|
|
$
|
0.10
|
|
|
$
|
0.075
|
|
|
$
|
0.28
|
|
|
$
|
0.21
|
|
|
Supplemental information (billions of dollars):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) Includes amounts related to crude oil
buy/sell arrangements:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating revenues
|
|
$
|
2.3
|
|
|
$
|
1.3
|
|
|
$
|
5.1
|
|
|
$
|
3.5
|
|
Cost of sales
|
|
|
2.3
|
|
|
|
1.3
|
|
|
|
5.1
|
|
|
|
3.5
|
|
(2) Includes excise taxes on sales by Valeros U.S.
retail system
|
|
$
|
0.2
|
|
|
$
|
0.2
|
|
|
$
|
0.6
|
|
|
$
|
0.6
|
|
See Condensed Notes to Consolidated Financial Statements.
4
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Millions of Dollars)
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
|
2005
|
|
|
2004
|
|
Cash flows from operating activities:
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
2,243
|
|
|
$
|
1,315
|
|
Adjustments to reconcile net income to net
cash provided by operating activities:
|
|
|
|
|
|
|
|
|
Depreciation and amortization expense
|
|
|
615
|
|
|
|
464
|
|
Noncash interest expense and other income, net
|
|
|
26
|
|
|
|
9
|
|
Deferred income tax expense
|
|
|
34
|
|
|
|
336
|
|
Changes in current assets and current liabilities
|
|
|
989
|
|
|
|
(141
|
)
|
Changes in deferred charges and credits and other, net
|
|
|
(62
|
)
|
|
|
(104
|
)
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
3,845
|
|
|
|
1,879
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash flows from investing activities:
|
|
|
|
|
|
|
|
|
Capital expenditures
|
|
|
(1,289
|
)
|
|
|
(821
|
)
|
Deferred turnaround and catalyst costs
|
|
|
(262
|
)
|
|
|
(180
|
)
|
Buyout of assets under structured lease arrangements
|
|
|
|
|
|
|
(567
|
)
|
Premcor Acquisition, net of cash acquired
|
|
|
(2,343
|
)
|
|
|
|
|
Aruba Acquisition, net of cash acquired
|
|
|
|
|
|
|
(548
|
)
|
Proceeds from the sale of the Denver Refinery
|
|
|
45
|
|
|
|
|
|
Contingent payments in connection with acquisitions
|
|
|
(85
|
)
|
|
|
(53
|
)
|
(Investment) return of investment in Cameron Highway
Oil Pipeline Project, net
|
|
|
40
|
|
|
|
(5
|
)
|
Proceeds from dispositions of property, plant and equipment
|
|
|
10
|
|
|
|
58
|
|
Minor acquisitions
|
|
|
(62
|
)
|
|
|
|
|
General partner contribution to Valero L.P.
|
|
|
(29
|
)
|
|
|
|
|
Other investing activities, net
|
|
|
6
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(3,969
|
)
|
|
|
(2,116
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash flows from financing activities:
|
|
|
|
|
|
|
|
|
Long-term debt borrowings, net of issuance costs
|
|
|
1,537
|
|
|
|
3,782
|
|
Long-term debt repayments
|
|
|
(1,421
|
)
|
|
|
(3,449
|
)
|
Proceeds from the sale of common stock, net of issuance costs
|
|
|
|
|
|
|
406
|
|
Issuance of common stock in connection with employee benefit
plans
|
|
|
146
|
|
|
|
112
|
|
Common and preferred stock dividends
|
|
|
(75
|
)
|
|
|
(58
|
)
|
Purchase of treasury stock
|
|
|
(188
|
)
|
|
|
(245
|
)
|
Other
|
|
|
(3
|
)
|
|
|
(1
|
)
|
|
|
|
|
|
|
|
Net cash provided by (used in) financing activities
|
|
|
(4
|
)
|
|
|
547
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of foreign exchange rate changes on cash
|
|
|
1
|
|
|
|
2
|
|
|
|
|
|
|
|
|
Net increase (decrease) in cash and temporary cash investments
|
|
|
(127
|
)
|
|
|
312
|
|
Cash and temporary cash investments at beginning of period
|
|
|
864
|
|
|
|
369
|
|
|
|
|
|
|
|
|
Cash and temporary cash investments at end of period
|
|
$
|
737
|
|
|
$
|
681
|
|
|
|
|
|
|
|
|
See Condensed Notes to Consolidated Financial Statements.
5
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Millions of Dollars)
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2005
|
|
|
2004
|
|
|
2005
|
|
|
2004
|
|
Net income
|
|
$
|
862
|
|
|
$
|
434
|
|
|
$
|
2,243
|
|
|
$
|
1,315
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other comprehensive income (loss):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Foreign currency translation adjustment
|
|
|
83
|
|
|
|
72
|
|
|
|
53
|
|
|
|
42
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss on derivative instruments
designated and qualifying as cash flow hedges:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss arising during the period,
net of income tax benefit of
$27, $32, $158 and $81
|
|
|
(50
|
)
|
|
|
(61
|
)
|
|
|
(294
|
)
|
|
|
(151
|
)
|
Net loss reclassified into income,
net of income tax benefit of
$15, $21, $86 and $9
|
|
|
28
|
|
|
|
39
|
|
|
|
161
|
|
|
|
17
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net loss on cash flow hedges
|
|
|
(22
|
)
|
|
|
(22
|
)
|
|
|
(133
|
)
|
|
|
(134
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other comprehensive income (loss)
|
|
|
61
|
|
|
|
50
|
|
|
|
(80
|
)
|
|
|
(92
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income
|
|
$
|
923
|
|
|
$
|
484
|
|
|
$
|
2,163
|
|
|
$
|
1,223
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See Condensed Notes to Consolidated Financial Statements.
6
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. BASIS OF PRESENTATION, PRINCIPLES OF CONSOLIDATION AND SIGNIFICANT ACCOUNTING POLICIES
As used in this report, the term Valero may refer to Valero Energy Corporation, one or more
of its consolidated subsidiaries, or all of them taken as a whole.
These unaudited consolidated financial statements include the accounts of Valero and subsidiaries
in which Valero has a controlling interest. Intercompany balances and transactions have been
eliminated in consolidation. Investments in 50% or less owned entities are accounted for using the
equity method of accounting.
These unaudited consolidated financial statements have been prepared in accordance with United
States generally accepted accounting principles (GAAP) for interim financial information and with
the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities Exchange Act of
1934. Accordingly, they do not include all of the information and notes required by GAAP for
complete consolidated financial statements. In the opinion of management, all adjustments
considered necessary for a fair presentation have been included. All such adjustments are of a
normal recurring nature unless disclosed otherwise. Financial information for the three and nine
months ended September 30, 2005 and 2004 included in these Condensed Notes to Consolidated
Financial Statements is derived from Valeros unaudited consolidated financial statements.
Operating results for the three and nine months ended September 30, 2005 are not necessarily
indicative of the results that may be expected for the year ending December 31, 2005.
The consolidated balance sheet as of December 31, 2004 has been derived from the audited financial
statements as of that date. For further information, refer to the consolidated financial
statements and notes thereto included in Valeros Annual Report on Form 10-K for the year ended
December 31, 2004.
Certain previously reported amounts have been reclassified to conform to the 2005 presentation.
2. ACCOUNTING PRONOUNCEMENTS
FASB Statement No. 123 (revised 2004)
In December 2004, the Financial Accounting Standards Board (FASB) issued Statement No. 123 (revised
2004), Share-Based Payment (Statement No. 123R), which will require the expensing of stock
options. In April 2005, the Securities and Exchange Commission (SEC) amended Rule 4-01(a) of
Regulation S-X to defer the required date for compliance with Statement No. 123R to the first
interim or annual reporting period of the registrants first fiscal year beginning on or after June
15, 2005 if the registrant is not a small business issuer. Valero intends to adopt Statement No.
123R on January 1, 2006, which complies with the amended Rule 4-01(a).
The adoption of Statement No. 123Rs fair value method will reduce Valeros results of operations,
but it will not have a material impact on Valeros overall financial position. The magnitude of
the impact of adoption of Statement No. 123R cannot be predicted at this time because it will
depend on levels of share-based incentive awards granted in the future. However, had Valero
adopted Statement No. 123R in prior periods, the impact of that standard would have approximated
the impact of Statement No. 123 as described in Note 13.
7
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Statement No. 123R also requires the benefits of tax deductions in excess of recognized
compensation cost to be reported as a financing cash flow, rather than as an operating cash flow as
required under current literature. This requirement will reduce cash flows from operating
activities and increase cash flows from financing activities in periods after adoption. While
Valero cannot estimate the magnitude of such amounts in the future because they depend on, among
other things, when employees exercise stock options, the amounts of operating cash flows recognized
for such excess tax deductions were $172 million and $48 million for the nine months ended
September 30, 2005 and 2004, respectively.
Under Valeros employee stock compensation plans, certain awards of stock options and restricted
stock provide that employees vest in the award when they retire or will continue to vest in the
award after retirement over the nominal vesting period established in the award. Valero has
accounted for such awards by recognizing compensation cost, if any, under APB Opinion No. 25 and
pro forma compensation cost under Statement No. 123, as disclosed in Note 13, over the nominal
vesting period. Upon the adoption of Statement No. 123R, Valero will change its method of
recognizing compensation cost to the non-substantive vesting period approach for any awards that
are granted after the adoption of Statement No. 123R. Under the non-substantive vesting period
approach, compensation cost will be recognized immediately for awards granted to
retirement-eligible employees or over the period from the grant date to the date retirement
eligibility is achieved if that date is expected to occur during the nominal vesting period. The
estimated after-tax effect related to the non-substantive vesting period approach is less than $3
million as described in Note 13.
FASB Interpretation No. 47
In March 2005, the FASB issued Interpretation No. 47, Accounting for Conditional Asset Retirement
Obligations (FIN 47). FIN 47 clarifies that the term conditional asset retirement obligation as
used in FASB Statement No. 143, Accounting for Asset Retirement Obligations, refers to a legal
obligation to perform an asset retirement activity in which the timing and/or method of settlement
are conditional on a future event that may or may not be within the control of the entity. Since
the obligation to perform the asset retirement activity is unconditional, FIN 47 provides that a
liability for the fair value of a conditional asset retirement obligation should be recognized if
that fair value can be reasonably estimated, even though uncertainty exists about the timing and/or
method of settlement. FIN 47 also clarifies when an entity would have sufficient information to
reasonably estimate the fair value of a conditional asset retirement obligation under FASB
Statement No. 143. FIN 47 is effective for fiscal years ending after December 15, 2005, and is not
expected to significantly affect Valeros financial position or results of operations.
EITF Issue No. 04-5
In June 2005, the FASB ratified its consensus on Emerging Issues Task Force (EITF) Issue No. 04-5,
Determining Whether a General Partner, or the General Partners as a Group, Controls a Limited
Partnership or Similar Entity When the Limited Partners Have Certain Rights (EITF No. 04-5), which
requires the general partner in a limited partnership to determine whether the limited partnership
is controlled by, and therefore should be consolidated by, the general partner. The guidance in
EITF No. 04-5 was effective after June 29, 2005 for general partners of all new partnerships formed
and for existing limited partnerships for which the partnership agreements are modified. For
general partners in all other limited partnerships, the guidance in EITF No. 04-5 is effective no
later than January 1, 2006. Valero will adopt EITF No. 04-5 effective January 1, 2006, the impact
of which is not expected to affect Valeros financial position or results of operations.
8
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
EITF Issue No. 04-13
Valeros operating revenues include sales related to certain buy/sell arrangements, which involve
linked purchases and sales related to crude oil contracts entered into to address location, quality
or grade requirements. In some cases, to obtain crude oil of a specific grade and quantity for
certain of Valeros refineries, Valero must agree to sell crude oil of a different grade and
quantity to its supplier at another location. Valero generally does not have the specific crude
oil to satisfy its suppliers needs and therefore must purchase that crude oil from a third party.
Valero sells the crude oil acquired from the third party to its crude oil supplier and recognizes
revenue on the sale and cost of sales at that time.
In September 2005, the FASB ratified its consensus on EITF Issue No. 04-13, Accounting for
Purchases and Sales of Inventory with the Same Counterparty (EITF No. 04-13), which requires that
inventory purchase and sales transactions with the same counterparty that are entered into in
contemplation of one another should be combined for purposes of applying AICPA Accounting
Principles Board (APB) Opinion No. 29, Accounting for Nonmonetary Transactions (APB No. 29). The guidance in EITF No. 04-13 is effective for transactions completed in reporting periods
beginning after March 15, 2006, with early application permitted. Valero expects to adopt EITF No.
04-13 on January 1, 2006.
One
issue addressed by EITF No. 04-13 details factors to consider in evaluating whether certain
individual transactions to purchase and sell inventory are made in contemplation of one another and
therefore should be viewed as one transaction when applying the principles of APB No. 29. When
applying these factors, Valeros buy/sell arrangements are deemed to be made in contemplation of
one another. Accordingly, upon adoption of EITF No. 04-13, Valeros buy/sell arrangements will be
accounted for as one transaction in applying the principles of APB No. 29. As a result, revenues
and cost of sales will cease to be recognized in connection with
these arrangements upon the
adoption of EITF No. 04-13 on January 1, 2006. This adoption will result in a reduction in Valeros
operating revenues in Valeros consolidated statement of income
and a corresponding reduction in
cost of sales with no expected impact on operating
income, net income or net income applicable to common stock. If EITF No. 04-13 had been applied by
Valero for the three and nine months ended September 30, 2005 and 2004, operating revenues and cost
of sales would have been reduced by the amounts reflected in the
supplemental information on the face of the consolidated statements of income.
3. ACQUISITIONS AND DISPOSITIONS
Premcor Acquisition
On September 1, 2005, Valero completed its merger with Premcor Inc. (Premcor). As used in this
report, Premcor Acquisition refers to the merger of Premcor with and into Valero. Premcor was an
independent petroleum refiner and supplier of unbranded transportation fuels, heating oil,
petrochemical feedstocks, petroleum coke and other petroleum products with all of its operations in
the United States. Premcor owned and operated refineries in Port Arthur, Texas; Lima, Ohio;
Memphis, Tennessee; and Delaware City, Delaware, with a combined crude oil throughput capacity of
approximately 800,000 barrels per day.
Under the terms of the merger agreement, each outstanding share of Premcor common stock was
converted into the right to receive cash or Valero common stock at the shareholders election,
subject to proration per the terms of the merger agreement, so that 50% of the total Premcor shares
(based on the number of Premcor shares outstanding at completion of the merger on a diluted basis
under the treasury stock method) was acquired for cash, with the balance acquired for Valero common
stock. Based on the election results, Premcors shareholders electing Valero common stock received 0.48233 of a share
of
9
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Valero common stock and $37.31 in cash for each share of Premcor common stock. Premcor
shareholders electing cash and non-electing shareholders received $72.76 in cash for each share of
Premcor common stock. As a result, Valero issued 42.5 million shares of Valero common stock and paid
$3.4 billion of cash to Premcor shareholders.
Valero incurred approximately $27 million of transaction costs to consummate the Premcor
Acquisition. In addition, Valero issued 7.1 million stock options in exchange for the 7.2 million
Premcor stock options outstanding as of September 1, 2005. The stock options issued by Valero had
a fair value of $596 million on the date of the merger, which was recorded in goodwill and
additional paid-in capital in Valeros consolidated balance sheet as of September 30, 2005. The
fair value of these stock options issued was estimated using the Black-Scholes option-pricing
model.
Valero paid the cash portion of the merger consideration from available cash and proceeds from a
$1.5 billion five-year bank term loan due in August 2010 (see Note 7 for additional details related
to the $1.5 billion term loan). In addition, Valero assumed Premcors existing debt, which had a
fair value of $1.9 billion as of September 1, 2005.
The Premcor Acquisition is consistent with Valeros general business strategy of increasing cash
flow and earnings through the acquisition of assets or businesses that are a logical extension of
its existing assets or businesses. The addition of Premcors assets has also increased the
geographic diversity of Valeros refining network by allowing Valero to expand into the midwestern
United States with the addition of Premcors Lima and Memphis Refineries. Valero believes that
Premcors assets provide profit improvement opportunities, which Valero believes it should be able
to realize given its history of increasing the reliability, capacity and yields of previously
acquired refineries.
The purchase price has been preliminarily allocated based on estimated fair values of the assets
acquired and the liabilities assumed at the date of acquisition, pending the completion of an
independent appraisal and other evaluations which are currently expected to be completed by
December 31, 2005. The purchase price and the preliminary purchase price allocation as of
September 30, 2005 were as follows (in millions):
|
|
|
|
|
Cash paid
|
|
$
|
3,377
|
|
Transaction costs
|
|
|
27
|
|
Less unrestricted cash acquired
|
|
|
(1,061
|
)
|
|
|
|
|
Premcor Acquisition, net of cash acquired,
as reflected on the consolidated statement of cash flows
|
|
|
2,343
|
|
Common stock
and stock options issued
|
|
|
3,773
|
|
|
|
|
|
Total purchase price, excluding unrestricted cash acquired
|
|
$
|
6,116
|
|
|
|
|
|
10
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
|
|
|
|
|
Current assets, net of unrestricted cash acquired
|
|
$
|
3,475
|
|
Property, plant and equipment
|
|
|
5,880
|
|
Intangible assets
|
|
|
5
|
|
Goodwill
|
|
|
2,529
|
|
Deferred charges and other assets
|
|
|
36
|
|
Current liabilities, less current portion
of long-term debt and capital lease obligations
|
|
|
(2,314
|
)
|
Long-term debt assumed, including current portion
|
|
|
(1,912
|
)
|
Capital lease obligation, including current portion
|
|
|
(14
|
)
|
Deferred income taxes
|
|
|
(1,237
|
)
|
Other long-term liabilities
|
|
|
(332
|
)
|
|
|
|
|
Purchase price, excluding
unrestricted cash acquired
|
|
$
|
6,116
|
|
|
|
|
|
Aruba Acquisition
On March 5, 2004, Valero completed the purchase of El Paso Corporations refinery located on the
island of Aruba in the Caribbean Sea (Aruba Refinery), and related marine, bunkering and marketing
operations (collectively, Aruba Acquisition). The final purchase price allocation was as follows
(in millions):
|
|
|
|
|
Current assets
|
|
$
|
323
|
|
Property, plant and equipment
|
|
|
498
|
|
Current liabilities
|
|
|
(172
|
)
|
Capital lease obligation
|
|
|
(3
|
)
|
Deferred income taxes
|
|
|
9
|
|
Other long-term liabilities
|
|
|
(20
|
)
|
|
|
|
|
Total purchase price
|
|
|
635
|
|
Less cash acquired
|
|
|
(94
|
)
|
|
|
|
|
Purchase price, excluding cash acquired
|
|
$
|
541
|
|
|
|
|
|
Unaudited Pro Forma Financial Information
The consolidated statements of income include the results of operations of the Premcor Acquisition
and the Aruba Acquisition commencing on September 1, 2005 and March 5, 2004, respectively. The
following unaudited pro forma financial information assumes:
|
|
|
42.5 million shares of common stock were issued, $1.5 billion of debt was incurred and
$1.9 billion of available cash was utilized to fund the Premcor Acquisition on January 1,
2005 and 2004 and
|
|
|
|
|
15.6 million shares of common stock were sold and approximately $36 million of debt was
incurred in connection with the Aruba Acquisition on January 1, 2004.
|
11
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
The unaudited pro forma financial information is not necessarily indicative of the results of
future operations (in millions, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2005
|
|
2004
|
|
2005
|
|
2004
|
Operating revenues
|
|
$
|
27,159
|
|
|
$
|
18,522
|
|
|
$
|
69,226
|
|
|
$
|
49,706
|
|
Operating income
|
|
|
1,621
|
|
|
|
934
|
|
|
|
4,473
|
|
|
|
2,696
|
|
Net income
|
|
|
1,049
|
|
|
|
554
|
|
|
|
2,838
|
|
|
|
1,548
|
|
Earnings per common share
|
|
|
3.44
|
|
|
|
1.85
|
|
|
|
9.40
|
|
|
|
5.14
|
|
Earnings per common share
assuming dilution
|
|
|
3.23
|
|
|
|
1.72
|
|
|
|
8.76
|
|
|
|
4.78
|
|
Sale of Denver Refinery
On May 31, 2005, Valero sold its Denver Refinery and related assets and liabilities to Suncor
Energy (U.S.A.) Inc. (Suncor) for $30 million plus approximately $15 million for working capital,
including feedstock and refined product inventories. In connection with this sale, Valero
recognized a pre-tax gain of $3 million, net of a reduction of $4 million for associated goodwill.
Sale of Equity Interest in Javelina Joint Venture
In September 2005, Valero entered into an agreement to sell its 20% equity interests in Javelina
Company and Javelina Pipeline Company (the Javelina Companies) to MarkWest Energy Partners, L.P.
(MarkWest). Javelina Company processes refinery off-gas at a plant in Corpus Christi, Texas. On
November 1, 2005, the sale was consummated and Valero received proceeds of $78 million from the
sale, resulting in a gain of approximately $55 million in the fourth quarter of 2005. In
conjunction with the sale, Valero also entered into gas processing and hydrogen purchase agreements
with MarkWest.
4. RESTRICTED CASH
Restricted cash as of September 30, 2005 and December 31, 2004 included $22 million of cash held in
trust related to change-in-control payments to be made to former officers and key employees of
Ultramar Diamond Shamrock Corporation (UDS) in connection with the UDS Acquisition that occurred in
December 2001. Restricted cash as of September 30, 2005 also included $67 million of cash which
was restricted to satisfy debt service requirements related to certain debt assumed in the Premcor
Acquisition.
5. INVENTORIES
Inventories consisted of the following (in millions):
|
|
|
|
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
2005
|
|
|
2004
|
|
Refinery feedstocks
|
|
$
|
2,085
|
|
|
$
|
877
|
|
Refined products and blendstocks
|
|
|
2,082
|
|
|
|
1,200
|
|
Convenience store merchandise
|
|
|
90
|
|
|
|
84
|
|
Materials and supplies
|
|
|
218
|
|
|
|
157
|
|
|
|
|
|
|
|
|
Inventories
|
|
$
|
4,475
|
|
|
$
|
2,318
|
|
|
|
|
|
|
|
|
12
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
As of September 30, 2005 and December 31, 2004, the replacement cost (market value) of LIFO
inventories exceeded their LIFO carrying amounts by approximately $5.9 billion and $1.2 billion,
respectively.
In determining the carrying amount of Valeros inventories as of September 30, 2005, Valero
recorded a $621 million charge to cost of sales in September 2005 resulting from the difference
between the fair market value recorded for the inventories acquired in the Premcor Acquisition
under purchase accounting and the amounts required to be recorded in applying Valeros LIFO
accounting policy.
6. INVESTMENT IN AND TRANSACTIONS WITH VALERO L.P.
As of December 31, 2004, Valero owned approximately 45.7% of Valero L.P., a limited partnership
that owns and operates crude oil and refined product pipeline, terminalling and storage tank
assets. On July 1, 2005, Valero L.P. completed its acquisition of Kaneb Pipe Line Partners, L.P.
(Kaneb Partners) and Kaneb Services LLC (together, the Kaneb Acquisition) in a transaction that
included the issuance of Valero L.P. common units in exchange for Kaneb Partners units. As a
result of the issuance of additional Valero L.P. common units for the Kaneb Acquisition, Valeros
ownership interest in Valero L.P. was reduced to 23.4%. In addition, Valero contributed $29
million to Valero L.P. to maintain Valeros 2% general partner interest in Valero L.P. Valeros
ownership interest in Valero L.P. remained at 23.4% as of September 30, 2005, which was composed of
a 2% general partner interest and a 21.4% limited partner interest represented by 627,530 common
units and 9,599,322 subordinated units of Valero L.P. Financial information reported by Valero
L.P. for the three and nine months ended September 30, 2005 and 2004 is summarized below (in
millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2005
|
|
2004
|
|
2005
|
|
2004
|
Revenues
|
|
$
|
263
|
|
|
$
|
58
|
|
|
$
|
378
|
|
|
$
|
166
|
|
Operating income
|
|
|
57
|
|
|
|
25
|
|
|
|
106
|
|
|
|
74
|
|
Net income
|
|
|
45
|
|
|
|
19
|
|
|
|
83
|
|
|
|
59
|
|
As of September 30, 2005 and December 31, 2004, Valeros receivables, net included $12 million
and $4 million, respectively, from Valero L.P., representing amounts due for employee costs,
insurance costs, operating expenses, administrative costs and rentals. As of September 30, 2005
and December 31, 2004, Valeros accounts payable included $21 million and $19 million,
respectively, to Valero L.P., representing amounts due for pipeline tariffs, terminalling fees and
tank rentals and fees.
Under a services agreement, Valero provides Valero L.P. with the corporate functions of legal,
accounting, treasury, engineering, information technology and other services for an administrative
services fee as prescribed by the services agreement. In addition, Valero charges Valero L.P. for
employee costs related to operating and maintenance services performed on certain Valero L.P.
assets. Valero also pays Valero L.P. certain fees under separate throughput, handling, terminalling
and service agreements with Valero L.P. The following table summarizes the results of transactions
with Valero L.P. (in millions):
13
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2005
|
|
2004
|
|
2005
|
|
2004
|
Fees and expenses charged by
Valero to Valero L.P.
|
|
$
|
30
|
|
|
$
|
12
|
|
|
$
|
52
|
|
|
$
|
31
|
|
Fees and expenses charged to
Valero by Valero L.P.
|
|
|
64
|
|
|
|
58
|
|
|
|
177
|
|
|
|
164
|
|
Historically, Valero L.P. has from time to time issued common units to the public, which have
diluted Valeros ownership percentage in Valero L.P. Such issuances have resulted in increases in
Valeros proportionate share of Valero L.P.s capital because the issuance price per unit exceeded
Valeros carrying amount per unit at the time of issuance. SEC Staff Accounting Bulletin No. 51,
Accounting for Sales of Stock by a Subsidiary, (SAB 51) provides guidance on accounting for the
effect of issuances of a subsidiarys stock on the parents investment in that subsidiary. SAB 51
allows registrants to elect an accounting policy of recording such increases or decreases in a
parents investment (SAB 51 credits or charges, respectively) either in income or directly in
equity.
As of June 30, 2005, prior to Valero L.P.s Kaneb Acquisition, Valero had approximately $7 million
in accumulated pre-tax SAB 51 credits related to its investment in Valero L.P. On July 1, 2005,
the issuance of common units by Valero L.P. in connection with the Kaneb Acquisition generated an
additional pre-tax SAB 51 credit of approximately $142 million for Valero. Valero has not
recognized any SAB 51 credits in its consolidated financial statements through September 30, 2005
and is not permitted to do so until its subordinated units convert to common units, which is
expected to occur on April 1, 2006. Valero expects to adopt its accounting policy and recognize
all of its cumulative SAB 51 credits at that time.
Effective July 1, 2005, Valero acquired Martin Oil Company LLC, a wholesale motor fuel marketer in
the midwestern United States, from Valero L.P. The acquisition cost was $26 million, $22 million
of which represented working capital acquired in the transaction.
7. LONG-TERM DEBT AND CAPITAL LEASE OBLIGATIONS
During January 2005, Valero repurchased $40 million of its 7.375% notes due in March 2006 and $42
million of its 6.125% notes due in April 2007 at a premium of $4 million. In addition, during the
nine months ended September 30, 2005, Valero made the following scheduled debt repayments:
|
|
|
$46 million during February 2005 related to its 7.44% medium-term notes,
|
|
|
|
$150 million during March 2005 related to its 8% medium-term notes,
|
|
|
|
$200 million during June 2005 related to its 8.375% notes, and
|
|
|
|
$13 million during August 2005 related to its 6.797% notes.
|
During the nine months ended September 30, 2005, Valero borrowed and repaid $40 million under its
prior $750 million three-year revolving bank credit facility.
In August 2005, Valero replaced its two $750 million revolving bank credit facilities with a $2.5
billion five-year revolving credit facility. The new revolving credit facility matures in August
2010. Borrowings under the new credit facility bear interest at LIBOR plus a margin, or an
alternate base rate as defined under the agreement. Valero will also be charged various fees and
expenses in connection with the
14
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
facility, including facility fees and letter of credit fees. The interest rate and fees under the
revolving bank credit facility are subject to adjustment based upon the credit ratings assigned to
Valeros long-term debt. The facility includes certain restrictive covenants including a coverage
ratio and a debt-to-capitalization ratio. As of September 30, 2005, there were no borrowings
outstanding under the revolving credit facility and outstanding letters of credit issued under the
facility totaled $514 million.
As discussed in Note 3, the cash portion of the Premcor Acquisition was partially financed with
proceeds received under a new $1.5 billion five-year bank term loan entered into by Valero in
August 2005. The term loan bears interest at LIBOR plus 75 basis points. During September 2005,
Valero repaid $700 million of this term loan, resulting in outstanding borrowings of $800 million
as of September 30, 2005. During October 2005, Valero repaid an additional $300 million of this
term loan.
In connection with the Premcor Acquisition, Valero assumed the following debt obligations, which
were recorded at fair value as of September 1, 2005:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Maturity
|
|
Par
|
|
Fair Value
|
Senior notes:
|
|
|
|
|
|
|
|
|
|
|
|
|
12.5%
|
|
|
2009
|
|
|
|
$ 161
|
|
|
|
$ 182
|
|
9.25%
|
|
|
2010
|
|
|
|
175
|
|
|
|
192
|
|
6.75%
|
|
|
2011
|
|
|
|
210
|
|
|
|
218
|
|
6.125%
|
|
|
2011
|
|
|
|
200
|
|
|
|
201
|
|
9.5%
|
|
|
2013
|
|
|
|
350
|
|
|
|
396
|
|
6.75%
|
|
|
2014
|
|
|
|
200
|
|
|
|
204
|
|
7.5%
|
|
|
2015
|
|
|
|
300
|
|
|
|
317
|
|
7.75% senior subordinated notes
|
|
|
2012
|
|
|
|
175
|
|
|
|
192
|
|
Ohio Water Development Authority
Environmental Facilities Revenue
Bonds
|
|
|
2031
|
|
|
|
10
|
|
|
|
10
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Debt assumed
|
|
|
|
|
|
|
$1,781
|
|
|
|
$1,912
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Generally, the debt obligations assumed in the Premcor Acquisition are unsecured with interest
payable semi-annually. During September 2005, Valero repurchased $190 million of the 7.75% senior
subordinated notes due in February 2012. Also in September 2005, Valero gave notice of its
intention to call for redemption the 12.5% senior notes due in January 2009. In October 2005,
Valero repurchased these 12.5% senior notes for $182 million.
Valero also assumed two capital lease obligations of Premcor, which had a fair value of $14 million
as of September 1, 2005.
15
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
8. STOCKHOLDERS EQUITY
Common
Stock Issuance
As
discussed in Note 3, on September 1, 2005, Valero issued 42.5 million
shares of common stock as partial consideration for the Premcor Acquisition. The common stock issued was recorded at a price of
$74.82 per share, representing the average price of Valeros
common stock from two days before to two days after the announcement
of the Premcor
Acquisition in April 2005, resulting in an aggregate recorded amount
of $3.2 billion for the common stock issued. In addition, Valero
issued stock options with a fair value of $596 million.
2% Mandatory Convertible Preferred Stock
During the nine months ended September 30, 2005, 6,425,743 shares of the preferred stock were
converted into 6,367,905 shares of Valero common stock. During October 2005, 347,306 additional
shares of the preferred stock were converted into 344,179 shares of Valero common stock.
On October 20, 2005, Valeros board of directors declared a dividend on the mandatory convertible
preferred stock of $0.125 per share payable on December 31, 2005 to holders of record at the close
of business on December 30, 2005.
Common Stock Purchases
During the nine months ended September 30, 2005 and 2004, Valero purchased 2.9 million and 8.0
million shares of its common stock at a cost of $188 million and $245 million, respectively, in
connection with the administration of its employee benefit plans.
Common Stock Dividends
On October 20, 2005, Valeros board of directors declared a regular quarterly cash dividend of
$0.10 per common share payable December 14, 2005 to holders of record at the close of business on
November 9, 2005.
Common Stock Split
On September 15, 2005, Valeros board of directors approved a two-for-one split of Valeros common
stock, to be effected in the form of a stock dividend, subject to shareholder approval of an
amendment to Valeros certificate of incorporation to increase the number of authorized shares. A
special meeting of Valeros shareholders is scheduled on December 1, 2005. If the amendment to
Valeros certificate of incorporation is approved, the payment of the stock dividend would occur on
December 15, 2005 to stockholders of record on December 2, 2005.
16
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
9. EARNINGS PER COMMON SHARE
Earnings per common share amounts were computed as follows (dollars and shares in millions, except
per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2005
|
|
|
2004
|
|
|
2005
|
|
|
2004
|
|
Earnings per Common Share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
862
|
|
|
$
|
434
|
|
|
$
|
2,243
|
|
|
$
|
1,315
|
|
Preferred stock dividends
|
|
|
4
|
|
|
|
3
|
|
|
|
12
|
|
|
|
9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income applicable to common stock
|
|
$
|
858
|
|
|
$
|
431
|
|
|
$
|
2,231
|
|
|
$
|
1,306
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted-average common shares outstanding
|
|
|
276
|
|
|
|
256
|
|
|
|
263
|
|
|
|
255
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per common share
|
|
$
|
3.11
|
|
|
$
|
1.69
|
|
|
$
|
8.49
|
|
|
$
|
5.13
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per Common Share Assuming Dilution:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income applicable to
common equivalent shares
|
|
$
|
862
|
|
|
$
|
434
|
|
|
$
|
2,243
|
|
|
$
|
1,315
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted-average common shares outstanding
|
|
|
276
|
|
|
|
256
|
|
|
|
263
|
|
|
|
255
|
|
Effect of dilutive securities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock options
|
|
|
11
|
|
|
|
7
|
|
|
|
10
|
|
|
|
7
|
|
Performance awards and other benefit plans
|
|
|
3
|
|
|
|
3
|
|
|
|
3
|
|
|
|
3
|
|
Mandatory convertible preferred stock
|
|
|
4
|
|
|
|
10
|
|
|
|
7
|
|
|
|
10
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted-average common equivalent
shares outstanding
|
|
|
294
|
|
|
|
276
|
|
|
|
283
|
|
|
|
275
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per common share assuming dilution
|
|
$
|
2.94
|
|
|
$
|
1.57
|
|
|
$
|
7.92
|
|
|
$
|
4.78
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
17
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
10.
|
|
STATEMENTS OF CASH FLOWS
|
|
|
|
In order to determine net cash provided by operating activities, net income is adjusted by, among
other things, changes in current assets and current liabilities as follows (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
|
2005
|
|
|
2004
|
|
Decrease (increase) in current assets:
|
|
|
|
|
|
|
|
|
Restricted cash
|
|
$
|
132
|
|
|
$
|
19
|
|
Receivables, net
|
|
|
(828
|
)
|
|
|
(742
|
)
|
Inventories
|
|
|
31
|
|
|
|
(648
|
)
|
Prepaid expenses and other
|
|
|
40
|
|
|
|
(7
|
)
|
Increase (decrease) in current liabilities:
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
|
1,533
|
|
|
|
937
|
|
Accrued expenses
|
|
|
40
|
|
|
|
198
|
|
Taxes other than income taxes
|
|
|
(100
|
)
|
|
|
(21
|
)
|
Income taxes payable
|
|
|
141
|
|
|
|
123
|
|
|
|
|
|
|
|
|
Changes in current assets and current liabilities
|
|
$
|
989
|
|
|
$
|
(141
|
)
|
|
|
|
|
|
|
|
The above changes in current assets and current liabilities differ from changes between amounts
reflected in the applicable consolidated balance sheets for the respective periods for the
following reasons:
|
|
|
the amounts shown above exclude changes in cash and temporary cash investments, deferred
income taxes, and current portion of long-term debt and capital lease obligations;
|
|
|
|
the amounts shown above exclude the current assets and current liabilities acquired in
connection with the Premcor Acquisition and certain minor acquisitions in 2005 and the
Aruba Acquisition in 2004, as well as the current assets and current liabilities disposed
of in connection with the sale of the Denver Refinery in 2005, all of which are reflected
separately in the consolidated statement of cash flows, and the effect of certain noncash
investing activities discussed below; and
|
|
|
|
certain differences between consolidated balance sheet changes and consolidated
statement of cash flow changes reflected above result from translating foreign currency
denominated amounts at different exchange rates.
|
Noncash investing and financing activities for the nine months ended September 30, 2005 included:
|
|
|
the issuance of $3.2 billion (42.5 million shares) of common stock and $596 million of
vested employee stock options as partial consideration for the Premcor Acquisition,
|
|
|
|
the conversion of 6,425,743 shares of preferred stock into 6,367,905 shares of Valero
common stock as discussed in Note 8, and
|
|
|
|
the recognition of a $28 million capital lease obligation and related capital lease
asset pertaining to certain equipment at Valeros Texas City Refinery.
|
Noncash investing activities for the nine months ended September 30, 2005 and 2004 included
adjustments to property, plant and equipment and certain current and noncurrent assets and
liabilities resulting from adjustments to the purchase price allocation related to the Aruba
Acquisition. Noncash investing activities for the nine months ended September 30, 2004 also
included adjustments to property, plant and equipment and certain current and noncurrent assets and
liabilities resulting from adjustments to
18
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
the purchase price allocation related to the acquisition of the St. Charles Refinery (St. Charles
Acquisition).
There were no significant noncash financing activities for the nine months ended September 30,
2004.
Cash flows related to interest and income taxes were as follows (in millions):
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
2005
|
|
2004
|
Interest paid (net of amount capitalized)
|
|
$
|
132
|
|
|
$
|
141
|
|
Income taxes paid, net of tax refunds received
|
|
|
881
|
|
|
|
232
|
|
11. PRICE RISK MANAGEMENT ACTIVITIES
The net gain (loss) recognized in income representing the amount of hedge ineffectiveness was as
follows (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 30,
|
|
September 30,
|
|
|
2005
|
|
2004
|
|
2005
|
|
2004
|
Fair value hedges
|
|
$
|
10
|
|
|
$
|
(1
|
)
|
|
$
|
13
|
|
|
$
|
3
|
|
Cash flow hedges
|
|
|
(28
|
)
|
|
|
(1
|
)
|
|
|
(28
|
)
|
|
|
(9
|
)
|
The above amounts were included in cost of sales in the consolidated statements of income. No
component of the derivative instruments gains or losses was excluded from the assessment of hedge
effectiveness. No amounts were recognized in income for hedged firm commitments that no longer
qualify as fair value hedges.
For cash flow hedges, gains and losses currently reported in accumulated other comprehensive
income in the consolidated balance sheets will be reclassified into income when the forecasted
transactions affect income. During the nine months ended September 30, 2005, Valero recognized in
accumulated other comprehensive income unrealized after-tax losses of $294 million on certain
cash flow hedges, primarily related to forward sales of distillates and associated forward
purchases of crude oil, with $182 million of cumulative after-tax losses on cash flow hedges
remaining in accumulated other comprehensive income as of September 30, 2005. Valero expects
that all of these cash flow hedges will be reclassified into income over the next 10 months as a
result of hedged transactions that are forecasted to occur. The amount ultimately realized in
income, however, will differ as commodity prices change. For the nine months ended September 30,
2005 and 2004, there were no amounts reclassified from accumulated other comprehensive income
into income as a result of the discontinuance of cash flow hedge accounting.
19
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
12. SEGMENT INFORMATION
Segment information for Valeros two reportable segments, refining and retail, was as follows (in
millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining
|
|
Retail
|
|
Corporate
|
|
Total
|
Three months ended September 30,
2005:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating revenues from external
customers
|
|
$
|
21,170
|
|
|
$
|
2,113
|
|
|
$
|
|
|
|
$
|
23,283
|
|
Intersegment revenues
|
|
|
1,484
|
|
|
|
|
|
|
|
|
|
|
|
1,484
|
|
Operating income (loss)
|
|
|
1,442
|
|
|
|
21
|
|
|
|
(152
|
)
|
|
|
1,311
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three months ended September 30,
2004:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating revenues from external
customers
|
|
|
12,720
|
|
|
|
1,619
|
|
|
|
|
|
|
|
14,339
|
|
Intersegment revenues
|
|
|
972
|
|
|
|
|
|
|
|
|
|
|
|
972
|
|
Operating income (loss)
|
|
|
760
|
|
|
|
36
|
|
|
|
(97
|
)
|
|
|
699
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine months ended September 30, 2005:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating revenues from external
customers
|
|
|
50,767
|
|
|
|
5,501
|
|
|
|
|
|
|
|
56,268
|
|
Intersegment revenues
|
|
|
3,691
|
|
|
|
|
|
|
|
|
|
|
|
3,691
|
|
Operating income (loss)
|
|
|
3,739
|
|
|
|
78
|
|
|
|
(355
|
)
|
|
|
3,462
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine months ended September 30, 2004:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating revenues from external
customers
|
|
|
34,613
|
|
|
|
4,615
|
|
|
|
|
|
|
|
39,228
|
|
Intersegment revenues
|
|
|
2,748
|
|
|
|
|
|
|
|
|
|
|
|
2,748
|
|
Operating income (loss)
|
|
|
2,341
|
|
|
|
122
|
|
|
|
(293
|
)
|
|
|
2,170
|
|
Total assets by reportable segment were as follows (in millions):
|
|
|
|
|
|
|
|
|
|
|
September 30,
|
|
|
December 31,
|
|
|
|
2005
|
|
|
2004
|
|
Refining
|
|
$
|
29,604
|
|
|
$
|
16,068
|
|
Retail
|
|
|
1,907
|
|
|
|
1,706
|
|
Corporate
|
|
|
1,263
|
|
|
|
1,618
|
|
|
|
|
|
|
|
|
Total consolidated assets
|
|
$
|
32,774
|
|
|
$
|
19,392
|
|
|
|
|
|
|
|
|
The entire balance of goodwill as of September 30, 2005 and December 31, 2004 has been included in
the total assets of the refining reportable segment.
13. STOCK-BASED COMPENSATION
Valero accounts for its employee stock compensation plans using the intrinsic value method of
accounting set forth in APB Opinion No. 25, Accounting for Stock Issued to Employees, and related
interpretations as permitted by Statement No. 123, Accounting for Stock-Based Compensation.
Because Valero accounts for its employee stock compensation plans using the intrinsic value method,
compensation cost is not recognized in the consolidated statements of income for Valeros fixed
stock option plans as all options granted have an exercise price equal to the market value of the
underlying
20
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
common stock on the date of grant. Had compensation cost for Valeros fixed stock option
plans been determined based on the grant-date fair value of awards consistent with the alternative
method set forth in Statement No. 123, Valeros net income applicable to common stock, net income
and earnings per common share, both with and without dilution, for the three and nine months ended
September 30, 2005 and 2004 would have been reduced to the pro forma amounts indicated below (in
millions, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
2005
|
|
|
2004
|
|
|
2005
|
|
|
2004
|
|
Net income applicable to common stock,
as reported
|
|
$
|
858
|
|
|
$
|
431
|
|
|
$
|
2,231
|
|
|
$
|
1,306
|
|
Deduct: Compensation expense on stock
options determined under fair value method
for all awards, net of related tax effects
|
|
|
(4
|
)
|
|
|
(3
|
)
|
|
|
(13
|
)
|
|
|
(12
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income applicable to
common stock
|
|
$
|
854
|
|
|
$
|
428
|
|
|
$
|
2,218
|
|
|
$
|
1,294
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As reported
|
|
$
|
3.11
|
|
|
$
|
1.69
|
|
|
$
|
8.49
|
|
|
$
|
5.13
|
|
Pro forma
|
|
|
3.09
|
|
|
|
1.67
|
|
|
|
8.43
|
|
|
|
5.08
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income, as reported
|
|
$
|
862
|
|
|
$
|
434
|
|
|
$
|
2,243
|
|
|
$
|
1,315
|
|
Deduct: Compensation expense on stock
options determined under fair value method
for all awards, net of related tax effects
|
|
|
(4
|
)
|
|
|
(3
|
)
|
|
|
(13
|
)
|
|
|
(12
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income
|
|
$
|
858
|
|
|
$
|
431
|
|
|
$
|
2,230
|
|
|
$
|
1,303
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per common share assuming dilution:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As reported
|
|
$
|
2.94
|
|
|
$
|
1.57
|
|
|
$
|
7.92
|
|
|
$
|
4.78
|
|
Pro forma
|
|
|
2.92
|
|
|
|
1.56
|
|
|
|
7.88
|
|
|
|
4.73
|
|
See Note 2 for a discussion of FASB Statement No. 123 (revised 2004) and the SECs amended Rule
4-01(a) of Regulation S-X, which will require Valero to change its accounting for stock-based
compensation beginning in 2006. Upon adoption of Statement No. 123R, Valero will change its
attribution approach for grants that have retirement-eligibility provisions from the nominal
vesting period approach utilized in the pro forma information presented above to the
non-substantive vesting period approach. If the non-substantive vesting period approach had been
used by Valero, the impact on the pro forma net income applicable to common stock and pro forma net
income amounts reflected above would have been less than $3 million for each of the periods
presented.
21
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
14. EMPLOYEE BENEFIT PLANS
The components of net periodic benefit cost related to Valeros defined benefit plans, including
those assumed in the Premcor Acquisition, were as follows for the three and nine months ended
September 30, 2005 and 2004 (in millions):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Postretirement
|
|
|
|
Pension Plans
|
|
|
Benefit Plans
|
|
|
|
2005
|
|
|
2004
|
|
|
2005
|
|
|
2004
|
|
Three months ended September 30:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Components of net periodic benefit cost:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
17
|
|
|
$
|
13
|
|
|
$
|
3
|
|
|
$
|
2
|
|
Interest cost
|
|
|
14
|
|
|
|
13
|
|
|
|
5
|
|
|
|
4
|
|
Expected return on plan assets
|
|
|
(13
|
)
|
|
|
(10
|
)
|
|
|
|
|
|
|
|
|
Amortization of:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Prior service cost
|
|
|
1
|
|
|
|
1
|
|
|
|
(2
|
)
|
|
|
(1
|
)
|
Net loss
|
|
|
3
|
|
|
|
1
|
|
|
|
1
|
|
|
|
1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net periodic benefit cost
|
|
$
|
22
|
|
|
$
|
18
|
|
|
$
|
7
|
|
|
$
|
6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine months ended September 30:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Components of net periodic benefit cost:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
50
|
|
|
$
|
41
|
|
|
$
|
7
|
|
|
$
|
6
|
|
Interest cost
|
|
|
41
|
|
|
|
37
|
|
|
|
13
|
|
|
|
12
|
|
Expected return on plan assets
|
|
|
(36
|
)
|
|
|
(31
|
)
|
|
|
|
|
|
|
|
|
Amortization of:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Prior service cost
|
|
|
2
|
|
|
|
2
|
|
|
|
(5
|
)
|
|
|
(5
|
)
|
Net loss
|
|
|
7
|
|
|
|
3
|
|
|
|
5
|
|
|
|
5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net periodic benefit cost
|
|
$
|
64
|
|
|
$
|
52
|
|
|
$
|
20
|
|
|
$
|
18
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Valeros anticipated contributions to its pension plans during 2005 have not changed from amounts
previously disclosed in Valeros consolidated financial statements for the year ended December 31,
2004. Valero has no minimum required contributions to its qualified pension plans during 2005
under the Employee Retirement Income Security Act. For the nine months ended September 30, 2005
and 2004, Valero contributed $60 million and $73 million, respectively, to its qualified pension
plans.
In connection with the Premcor Acquisition, Valero became the plan sponsor for three additional
pension plans and two additional other postretirement benefit plans. Prior to September 1, 2005,
Premcor had contributed $20 million to the former Premcor pension plans; Valero does not plan to
make further contributions to these plans in 2005.
15. COMMITMENTS AND CONTINGENCIES
Accounts Receivable Sales Facility
As of December 31, 2004, Valero had an accounts receivable sales facility with a group of
third-party financial institutions to sell on a revolving basis up to $600 million of eligible
trade and credit card receivables, which was to mature in October 2005. In August 2005, Valero
amended this agreement to, among other things: (i) remove the credit card receivables from the
eligible pool of receivables,
22
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(ii) increase the size of the facility by $400 million to $1 billion, and (iii) extend the maturity date
to August 2008. As of September 30, 2005 and December 31, 2004, the amount of eligible receivables
sold to the third-party financial institutions was $1 billion and $600 million, respectively.
Contingent Earn-Out Agreements
In the second quarter of 2005 and 2004, Valero made earn-out contingency payments of $35 million
each year to Salomon Inc in connection with Valeros acquisition of Basis Petroleum, Inc., which
were recorded as increases to goodwill. In January 2005, Valero also made a previously accrued
earn-out payment related to the St. Charles Acquisition of $50 million.
The Delaware City Refinery was acquired by Premcor in May 2004 from Motiva Enterprises LLC
(Motiva). In connection with that acquisition, Motiva is entitled to receive two separate annual
earn-out contingency payments depending on (a) the amount of crude oil processed at the refinery
and the level of refining margins for the three years following the acquisition, and (b) the
achievement of certain performance criteria at the refinerys gasification facility for the two
years following the acquisition. For the first year following the acquisition, Premcor paid the
$25 million annual maximum amount under the margin contingency but was not obligated to make any
payment related to the gasification facility performance.
The following table summarizes the aggregate payments made by Valero and payment limitations
related to the following acquisitions (in millions). The margin contingency payment for the
Delaware City Refinery reflected below was made by Premcor prior to its acquisition by Valero.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Aggregate
|
|
|
|
|
|
|
Payments
|
|
Annual
|
|
|
|
|
Made Through
|
|
Maximum
|
|
Aggregate
|
|
|
September 30, 2005
|
|
Limit
|
|
Limit
|
Basis
Petroleum, Inc.
|
|
$
|
174
|
|
|
$
|
35
|
|
|
$
|
200
|
|
St. Charles Refinery
|
|
|
50
|
|
|
|
50
|
|
|
|
175
|
|
Delaware City Refinery:
|
|
|
|
|
|
|
|
|
|
|
|
|
Margin contingency
|
|
|
25
|
|
|
|
25
|
|
|
|
75
|
|
Gasification facility performance
|
|
|
|
|
|
|
25
|
|
|
|
50
|
|
Environmental Matters
The Environmental Protection Agencys (EPA) Tier II Gasoline and Diesel Standards
. The EPAs Tier
II standards, adopted under the Clean Air Act, phase in limitations on the sulfur content of
gasoline (which began in 2004) and diesel fuel sold to highway consumers (beginning in 2006). Most
of Valeros refineries are being modified to comply with the Tier II gasoline and diesel standards.
Valero believes that capital expenditures of approximately $2.6 billion will be required through
2008 for its refineries to meet the Tier II specifications, of which approximately $1.8 billion has
been spent through September 30, 2005. This estimate includes post-acquisition investments at the
former Premcor refineries and amounts related to projects at five Valero refineries to provide
hydrogen necessary for removing sulfur from gasoline and diesel. Valero expects that its cost
estimates will change as additional engineering is completed and progress is made toward
construction of these various projects.
23
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
EPAs Section 114 Initiative.
In 2000, the EPA issued to Valero an information request pursuant to
Section 114 of the Clean Air Act as part of the EPAs National Petroleum Refinery Initiative to
reduce air emissions (Initiative). On June 16, 2005, the EPA and the U.S. Department of Justice
(DOJ) announced a comprehensive settlement with Valero in connection with the Initiative. The
states of Colorado, Louisiana, New Jersey, Oklahoma and Texas joined the EPA in the settlement.
The EPAs consent decree (lodged June 16, 2005 in the U.S. District Court for the Western District
of Texas) will require Valero to invest approximately $785 million in environmental projects
through 2012 to reduce emissions across Valeros U.S. refining system. All state and federal
comment periods applicable to the consent decree have lapsed. Valero expects the court to enter
the decree in the fourth quarter of 2005.
Three refineries acquired by Valero in the Premcor Acquisition (the Port Arthur, Memphis and Lima
Refineries) had also received several information requests from the EPA in connection with the
Initiative (the Delaware City Refinery is already subject to a Section 114 settlement). The EPA
recently invited Valero to enter into Initiative settlement discussions concerning these three
refineries. Valero expects to begin settlement meetings with the EPA in the near future. Valero
expects to incur penalties and related expenses in connection with a potential settlement, but
Valero believes that any settlement penalties will be immaterial to its results of operations and
financial position. In addition, Valero expects that a settlement will require significant capital
improvements or changes in operating parameters, or both, at the three refineries.
Houston/Galveston SIP
. Valeros Houston and Texas City Refineries are located in the
Houston-Galveston ozone nonattainment area, which was classified as severe under the EPAs
one-hour
ambient air quality standard for ozone. In December 2002, the Texas Commission on
Environmental Quality (TCEQ) developed a plan to bring the Houston-Galveston area into compliance
with the one-hour standard. The TCEQ plan requires industry sources to reduce emissions of
nitrogen oxides (NOx) by an average of 80% from a 1997-1999 average actual emissions baseline, and
an area-wide 64% reduction in certain highly reactive volatile organic compounds (HRVOCs). Per
the TCEQs plan, Valero is required to install NOx and HRVOC controls and monitoring equipment and
implement certain operating practices during 2005-2007 at its Houston and Texas City Refineries at
a cost estimated by Valero to be approximately $68 million.
In April 2004, the EPA designated the Houston-Galveston area as being in moderate nonattainment
of the EPAs
eight-hour
ambient air quality standard for ozone, and established an attainment
deadline (under the eight-hour standard) of 2010. Effective June 2005, the EPA revoked its
one-hour standard for ozone compliance in favor of the stricter eight-hour standard. However,
because of anti-backsliding provisions of the EPAs eight-hour ozone regulations, the TCEQ was
required to retain the NOx and HRVOC regulations established for the prior one-hour standard.
Accordingly, Valero must install the NOx and HRVOC controls and monitoring equipment required under
the TCEQs regulations for the prior one-hour standard. The EPAs eight-hour ozone standard will
require the TCEQ to design and submit to the EPA by 2007 a proposed state implementation plan for
the eight-hour standard, which likely will require additional controls by 2009.
24
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Litigation
Union Oil Company of California v. Valero Energy Corporation
, United States District Court, Central
District of California (filed January 22, 2002). In 2002, Union Oil Company of California (Unocal)
sued Valero alleging patent infringement. The complaint sought a 5.75 cent per gallon royalty on
all reformulated gasoline infringing on Unocals '393 and
'126 patents as well as treble damages
for Valeros alleged willful infringement of Unocals patents and Valeros alleged conduct to
induce others to infringe the patents. In accordance with the Federal Trade Commissions consent
decree approving Chevron Corporations acquisition of Unocal, Unocals lawsuit against Valero was
required to be dismissed after completion of the acquisition on August 10, 2005. The parties
agreed motion to dismiss was granted by the court on August 23, 2005.
MTBE Litigation
As of October 31, 2005, Valero was named as a defendant in 64 cases alleging liability related to
MTBE contamination in groundwater. (Premcor, now included within Valero, was also separately
named in 53 of these cases.) The plaintiffs are generally water providers, governmental
authorities and private water companies alleging that refiners and marketers of MTBE and gasoline
containing MTBE are liable for manufacturing or distributing a defective product. Valero is named
in these suits together with many other refining industry companies. Valero is being sued
primarily as a refiner and marketer of MTBE and gasoline containing MTBE. Valero does not own or
operate gasoline station facilities in most of the geographic locations in which damage is alleged
to have occurred. The suits generally seek individual, unquantified compensatory and punitive
damages and attorneys fees. All but one of these cases have been removed to federal court by the
defendants and have been consolidated for pre-trial proceedings in the U.S. District Court for the
Southern District of New York (Multi-District Litigation Docket No. 1358,
In re: Methyl-Tertiary
Butyl Ether Products Liability Litigation
). Four of these cases have been selected by the court as
focus cases for discovery and pre-trial motions. Activity in the non-focus cases is generally
stayed pending certain determinations in the focus cases. Valero believes that it has strong
defenses to these claims and is vigorously defending the cases. Valero believes that an adverse
result in any one of these suits would not have a material effect on its results of operations or
financial position. However, Valero believes that an adverse result in all or a substantial number
of these cases could have a material effect on Valeros results of operations and financial
position. An estimate of the possible loss or range of loss from an adverse result in all or
substantially all of these cases cannot reasonably be made.
Rosolowski v. Clark Refining & Marketing, Inc., et al.
, Judicial Circuit Court, Cook County,
Illinois (Case No. 95-L 014703). This class action lawsuit, filed October 11, 1995, relates in
part to a release to the atmosphere of spent catalyst containing low levels of heavy metals from
the now-closed Blue Island, Illinois refinery on October 7, 1994. The release resulted in the
temporary evacuation of certain areas near the refinery. The case was certified as a class action
in 2000 with three classes: (1) persons purportedly affected by the October 7, 1994 catalyst
release, but with no permanent health effects; (2) persons with medical expenses for dependents
purportedly affected by the October 7, 1994 release; and (3) local residents claiming property
damage or who have suffered loss of use and enjoyment of their property over a period of several
years. The lawsuit was once consolidated with another purported class action, but was recently
deconsolidated in anticipation of the beginning of trial. Trial began October 31, 2005. Valero
believes that an adverse result in this case could have a material effect on Valeros results of
operations and financial position. An estimate of the possible loss or range of loss from an
adverse result in this case cannot reasonably be made.
25
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Other Litigation
Valero is also a party to additional claims and legal proceedings arising in the ordinary course of
business. Valero believes it is unlikely that the final outcome of any of the claims or
proceedings to which it is a party would have a material adverse effect on its financial position,
results of operations or liquidity; however, due to the inherent uncertainty of litigation, the
range of possible loss, if any, cannot be estimated with a reasonable degree of precision and there
can be no assurance that the resolution of any particular claim or proceeding would not have an
adverse effect on Valeros results of operations, financial position or liquidity.
16. CONDENSED CONSOLIDATING FINANCIAL INFORMATION
In conjunction with the Premcor Acquisition on September 1, 2005, Valero Energy
Corporation has fully and unconditionally guaranteed the following debt of The Premcor
Refining Group Inc. (PRG), an indirect wholly owned subsidiary of Valero Energy
Corporation:
|
|
|
9.25% senior notes due February 2010,
|
|
|
|
6.75% senior notes due February 2011,
|
|
|
|
6.125% senior notes due February 2011,
|
|
|
|
9.5% senior notes due February 2013,
|
|
|
|
6.75% senior notes due February 2014,
|
|
|
|
7.5% senior notes due June 2015, and
|
|
|
|
Ohio Water Development Authority Environmental Facilities Revenue Bonds due
December 2031.
|
In addition, PRG has fully and unconditionally guaranteed all of the outstanding debt
issued by Valero Energy Corporation.
The following condensed consolidating financial information is provided for Valero
Energy Corporation and PRG as an alternative to providing separate financial statements
for PRG for the periods subsequent to the Premcor Acquisition. The accounts for all
companies reflected herein are presented using the equity method of accounting for
investments in subsidiaries.
26
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Condensed Consolidating Balance Sheet as of September 30, 2005 (unaudited, in millions)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Valero
|
|
|
|
|
|
|
Other Non-
|
|
|
|
|
|
|
|
|
|
Energy
|
|
|
|
|
|
|
Guarantor
|
|
|
|
|
|
|
|
|
|
Corporation
|
|
|
PRG
|
|
|
Subsidiaries
|
|
|
Eliminations
|
|
|
Consolidated
|
|
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and temporary cash investments
|
|
$
|
221
|
|
|
$
|
25
|
|
|
$
|
491
|
|
|
$
|
|
|
|
$
|
737
|
|
Restricted cash
|
|
|
22
|
|
|
|
11
|
|
|
|
57
|
|
|
|
|
|
|
|
90
|
|
Receivables, net
|
|
|
4
|
|
|
|
899
|
|
|
|
2,651
|
|
|
|
(1
|
)
|
|
|
3,553
|
|
Inventories
|
|
|
|
|
|
|
1,350
|
|
|
|
3,125
|
|
|
|
|
|
|
|
4,475
|
|
Deferred income taxes
|
|
|
5
|
|
|
|
|
|
|
|
147
|
|
|
|
(152
|
)
|
|
|
|
|
Prepaid expenses and other
|
|
|
1
|
|
|
|
160
|
|
|
|
96
|
|
|
|
|
|
|
|
257
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
253
|
|
|
|
2,445
|
|
|
|
6,567
|
|
|
|
(153
|
)
|
|
|
9,112
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, at cost
|
|
|
|
|
|
|
4,646
|
|
|
|
14,865
|
|
|
|
|
|
|
|
19,511
|
|
Accumulated depreciation
|
|
|
|
|
|
|
(10
|
)
|
|
|
(2,349
|
)
|
|
|
|
|
|
|
(2,359
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net
|
|
|
|
|
|
|
4,636
|
|
|
|
12,516
|
|
|
|
|
|
|
|
17,152
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Intangible assets, net
|
|
|
|
|
|
|
5
|
|
|
|
302
|
|
|
|
|
|
|
|
307
|
|
Goodwill
|
|
|
|
|
|
|
2,529
|
|
|
|
2,434
|
|
|
|
|
|
|
|
4,963
|
|
Investment in subsidiaries
|
|
|
6,813
|
|
|
|
438
|
|
|
|
3,429
|
|
|
|
(10,680
|
)
|
|
|
|
|
Long-term notes receivable from affiliates
|
|
|
11,695
|
|
|
|
|
|
|
|
|
|
|
|
(11,695
|
)
|
|
|
|
|
Investment in Valero L.P.
|
|
|
|
|
|
|
|
|
|
|
292
|
|
|
|
|
|
|
|
292
|
|
Deferred income taxes
|
|
|
195
|
|
|
|
|
|
|
|
|
|
|
|
(195
|
)
|
|
|
|
|
Deferred charges and other assets, net
|
|
|
123
|
|
|
|
42
|
|
|
|
800
|
|
|
|
(17
|
)
|
|
|
948
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$
|
19,079
|
|
|
$
|
10,095
|
|
|
$
|
26,340
|
|
|
$
|
(22,740
|
)
|
|
$
|
32,774
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current portion of long-term debt
and capital lease obligations
|
|
$
|
220
|
|
|
$
|
|
|
|
$
|
49
|
|
|
$
|
|
|
|
$
|
269
|
|
Accounts payable
|
|
|
21
|
|
|
|
941
|
|
|
|
5,007
|
|
|
|
|
|
|
|
5,969
|
|
Accrued expenses
|
|
|
140
|
|
|
|
102
|
|
|
|
742
|
|
|
|
|
|
|
|
984
|
|
Taxes other than income taxes
|
|
|
|
|
|
|
50
|
|
|
|
420
|
|
|
|
|
|
|
|
470
|
|
Income taxes payable
|
|
|
124
|
|
|
|
|
|
|
|
51
|
|
|
|
(1
|
)
|
|
|
174
|
|
Deferred income taxes
|
|
|
|
|
|
|
273
|
|
|
|
|
|
|
|
(152
|
)
|
|
|
121
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
505
|
|
|
|
1,366
|
|
|
|
6,269
|
|
|
|
(153
|
)
|
|
|
7,987
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term debt and capital lease obligations,
less current portion
|
|
|
4,387
|
|
|
|
1,539
|
|
|
|
183
|
|
|
|
|
|
|
|
6,109
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term notes payable to affiliates
|
|
|
|
|
|
|
1,926
|
|
|
|
9,769
|
|
|
|
(11,695
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income taxes
|
|
|
|
|
|
|
1,064
|
|
|
|
2,551
|
|
|
|
(195
|
)
|
|
|
3,420
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other long-term liabilities
|
|
|
376
|
|
|
|
334
|
|
|
|
754
|
|
|
|
|
|
|
|
1,464
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stockholders equity:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred stock
|
|
|
76
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
76
|
|
Common stock
|
|
|
3
|
|
|
|
|
|
|
|
1
|
|
|
|
(1
|
)
|
|
|
3
|
|
Additional paid-in capital
|
|
|
8,307
|
|
|
|
4,020
|
|
|
|
4,011
|
|
|
|
(8,048
|
)
|
|
|
8,290
|
|
Treasury stock
|
|
|
(83
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(83
|
)
|
Retained earnings (accumulated deficit)
|
|
|
5,359
|
|
|
|
(154
|
)
|
|
|
2,709
|
|
|
|
(2,555
|
)
|
|
|
5,359
|
|
Accumulated other comprehensive income
|
|
|
149
|
|
|
|
|
|
|
|
93
|
|
|
|
(93
|
)
|
|
|
149
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
13,811
|
|
|
|
3,866
|
|
|
|
6,814
|
|
|
|
(10,697
|
)
|
|
|
13,794
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
|
|
$
|
19,079
|
|
|
$
|
10,095
|
|
|
$
|
26,340
|
|
|
$
|
(22,740
|
)
|
|
$
|
32,774
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
27
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Condensed
Consolidating Statements of Income for the Three Months Ended September 30, 2005 (unaudited, in millions)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Valero
|
|
|
|
|
|
|
Other Non-
|
|
|
|
|
|
|
|
|
|
Energy
|
|
|
|
|
|
|
Guarantor
|
|
|
|
|
|
|
|
|
|
Corporation
|
|
|
PRG (1)
|
|
|
Subsidiaries
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Operating revenues
|
|
$
|
|
|
|
$
|
5,447
|
|
|
$
|
17,995
|
|
|
$
|
(159
|
)
|
|
$
|
23,283
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales
|
|
|
|
|
|
|
5,726
|
|
|
|
15,071
|
|
|
|
(159
|
)
|
|
|
20,638
|
|
Refining operating expenses
|
|
|
|
|
|
|
83
|
|
|
|
689
|
|
|
|
|
|
|
|
772
|
|
Retail selling expenses
|
|
|
|
|
|
|
|
|
|
|
201
|
|
|
|
|
|
|
|
201
|
|
General and administrative expenses
|
|
|
|
|
|
|
14
|
|
|
|
115
|
|
|
|
|
|
|
|
129
|
|
Depreciation and amortization expense
|
|
|
|
|
|
|
11
|
|
|
|
221
|
|
|
|
|
|
|
|
232
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
|
|
|
|
5,834
|
|
|
|
16,297
|
|
|
|
(159
|
)
|
|
|
21,972
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (loss)
|
|
|
|
|
|
|
(387
|
)
|
|
|
1,698
|
|
|
|
|
|
|
|
1,311
|
|
Equity in earnings (loss) of subsidiaries (2)
|
|
|
836
|
|
|
|
77
|
|
|
|
(231
|
)
|
|
|
(682
|
)
|
|
|
|
|
Equity in earnings of Valero L.P.
|
|
|
|
|
|
|
|
|
|
|
13
|
|
|
|
|
|
|
|
13
|
|
Other income (expense), net
|
|
|
126
|
|
|
|
3
|
|
|
|
9
|
|
|
|
(127
|
)
|
|
|
11
|
|
Interest and debt expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Incurred
|
|
|
(85
|
)
|
|
|
(9
|
)
|
|
|
(118
|
)
|
|
|
127
|
|
|
|
(85
|
)
|
Capitalized
|
|
|
|
|
|
|
3
|
|
|
|
15
|
|
|
|
|
|
|
|
18
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before income tax expense
|
|
|
877
|
|
|
|
(313
|
)
|
|
|
1,386
|
|
|
|
(682
|
)
|
|
|
1,268
|
|
Income tax expense (benefit) (3)
|
|
|
15
|
|
|
|
(159
|
)
|
|
|
550
|
|
|
|
|
|
|
|
406
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
862
|
|
|
|
(154
|
)
|
|
|
836
|
|
|
|
(682
|
)
|
|
|
862
|
|
Preferred stock dividends
|
|
|
4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) applicable to common stock
|
|
$
|
858
|
|
|
$
|
(154
|
)
|
|
$
|
836
|
|
|
$
|
(682
|
)
|
|
$
|
858
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
Cost of sales of PRG for the three months ended September 30, 2005 includes the
effect of a $621 million LIFO charge related to the difference between the fair market
value recorded for the inventories acquired in the Premcor Acquisition under purchase
accounting and the amounts required to be recorded in applying Valeros LIFO accounting
policy.
|
|
(2)
|
|
Equity in loss of subsidiary in the Other Non-Guarantor Subsidiaries column differs
from PRGs net loss due to the exclusion of PRGs equity in earnings of subsidiaries from
PRGs income to avoid duplication. The earnings of PRGs subsidiaries are included on a
line-by-line basis in the Other Non-Guarantor Subsidiaries column.
|
|
(3)
|
|
The income tax expense (benefit) reflected in each column does not include any tax
effect of the equity in earnings (loss) of subsidiaries.
|
28
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Condensed
Consolidating Statements of Income for the Nine Months Ended September 30, 2005 (unaudited, in millions)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Valero
|
|
|
|
|
|
|
Other Non-
|
|
|
|
|
|
|
|
|
|
Energy
|
|
|
|
|
|
|
Guarantor
|
|
|
|
|
|
|
|
|
|
Corporation
|
|
|
PRG (1)
|
|
|
Subsidiaries
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Operating revenues
|
|
$
|
|
|
|
$
|
5,447
|
|
|
$
|
51,371
|
|
|
$
|
(550
|
)
|
|
$
|
56,268
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales
|
|
|
|
|
|
|
5,726
|
|
|
|
44,213
|
|
|
|
(550
|
)
|
|
|
49,389
|
|
Refining operating expenses
|
|
|
|
|
|
|
83
|
|
|
|
1,855
|
|
|
|
|
|
|
|
1,938
|
|
Retail selling expenses
|
|
|
|
|
|
|
|
|
|
|
561
|
|
|
|
|
|
|
|
561
|
|
General and administrative expenses
|
|
|
2
|
|
|
|
14
|
|
|
|
287
|
|
|
|
|
|
|
|
303
|
|
Depreciation and amortization expense
|
|
|
|
|
|
|
11
|
|
|
|
604
|
|
|
|
|
|
|
|
615
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
2
|
|
|
|
5,834
|
|
|
|
47,520
|
|
|
|
(550
|
)
|
|
|
52,806
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (loss)
|
|
|
(2
|
)
|
|
|
(387
|
)
|
|
|
3,851
|
|
|
|
|
|
|
|
3,462
|
|
Equity in earnings (loss) of subsidiaries (2)
|
|
|
2,151
|
|
|
|
77
|
|
|
|
(231
|
)
|
|
|
(1,997
|
)
|
|
|
|
|
Equity in earnings of Valero L.P.
|
|
|
|
|
|
|
|
|
|
|
32
|
|
|
|
|
|
|
|
32
|
|
Other income (expense), net
|
|
|
396
|
|
|
|
3
|
|
|
|
13
|
|
|
|
(416
|
)
|
|
|
(4
|
)
|
Interest and debt expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Incurred
|
|
|
(250
|
)
|
|
|
(9
|
)
|
|
|
(387
|
)
|
|
|
416
|
|
|
|
(230
|
)
|
Capitalized
|
|
|
|
|
|
|
3
|
|
|
|
36
|
|
|
|
|
|
|
|
39
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before income tax expense
|
|
|
2,295
|
|
|
|
(313
|
)
|
|
|
3,314
|
|
|
|
(1,997
|
)
|
|
|
3,299
|
|
Income tax expense (benefit) (3)
|
|
|
52
|
|
|
|
(159
|
)
|
|
|
1,163
|
|
|
|
|
|
|
|
1,056
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
2,243
|
|
|
|
(154
|
)
|
|
|
2,151
|
|
|
|
(1,997
|
)
|
|
|
2,243
|
|
Preferred stock dividends
|
|
|
12
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) applicable to common stock
|
|
$
|
2,231
|
|
|
$
|
(154
|
)
|
|
$
|
2,151
|
|
|
$
|
(1,997
|
)
|
|
$
|
2,231
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
Cost of sales of PRG for the nine months ended September 30, 2005 includes the effect
of a $621 million LIFO charge related to the difference between the fair market value
recorded for the inventories acquired in the Premcor Acquisition under purchase accounting
and the amounts required to be recorded in applying Valeros LIFO accounting policy.
|
|
(2)
|
|
Equity in loss of subsidiary in the Other Non-Guarantor Subsidiaries column differs
from PRGs net loss due to the exclusion of PRGs equity in earnings of subsidiaries from
PRGs income to avoid duplication. The earnings of PRGs subsidiaries are included on a
line-by-line basis in the Other Non-Guarantor Subsidiaries column.
|
|
(3)
|
|
The income tax expense (benefit) reflected in each column does not include any tax
effect of the equity in earnings (loss) of subsidiaries.
|
29
VALERO ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
Condensed
Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2005 (unaudited, in millions)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Valero
|
|
|
|
|
|
|
Other Non-
|
|
|
|
|
|
|
|
|
|
Energy
|
|
|
|
|
|
|
Guarantor
|
|
|
|
|
|
|
|
|
|
Corporation
|
|
|
PRG
|
|
|
Subsidiaries
|
|
|
Eliminations
|
|
|
Consolidated
|
|
Net cash provided by operating activities
|
|
$
|
140
|
|
|
$
|
79
|
|
|
$
|
3,626
|
|
|
$
|
|
|
|
$
|
3,845
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash flows from investing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital expenditures
|
|
|
|
|
|
|
(66
|
)
|
|
|
(1,223
|
)
|
|
|
|
|
|
|
(1,289
|
)
|
Deferred turnaround and catalyst costs
|
|
|
|
|
|
|
(6
|
)
|
|
|
(256
|
)
|
|
|
|
|
|
|
(262
|
)
|
Premcor Acquisition, net of cash acquired
|
|
|
(2,343
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,343
|
)
|
Net intercompany (loans) receipts
|
|
|
1,949
|
|
|
|
|
|
|
|
|
|
|
|
(1,949
|
)
|
|
|
|
|
Other investing activities, net
|
|
|
(35
|
)
|
|
|
|
|
|
|
(40
|
)
|
|
|
|
|
|
|
(75
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing
activities
|
|
|
(429
|
)
|
|
|
(72
|
)
|
|
|
(1,519
|
)
|
|
|
(1,949
|
)
|
|
|
(3,969
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash flows from financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term debt borrowings, net of issuance costs
|
|
|
1,537
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,537
|
|
Long-term debt repayments
|
|
|
(1,231
|
)
|
|
|
(190
|
)
|
|
|
|
|
|
|
|
|
|
|
(1,421
|
)
|
Purchase of treasury stock
|
|
|
(188
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(188
|
)
|
Net intercompany borrowings (repayments)
|
|
|
|
|
|
|
208
|
|
|
|
(2,157
|
)
|
|
|
1,949
|
|
|
|
|
|
Other financing activities, net
|
|
|
70
|
|
|
|
|
|
|
|
(2
|
)
|
|
|
|
|
|
|
68
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) financing
activities
|
|
|
188
|
|
|
|
18
|
|
|
|
(2,159
|
)
|
|
|
1,949
|
|
|
|
(4
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of foreign exchange rate changes on cash
|
|
|
|
|
|
|
|
|
|
|
1
|
|
|
|
|
|
|
|
1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net increase (decrease) in cash and temporary cash
investments
|
|
|
(101
|
)
|
|
|
25
|
|
|
|
(51
|
)
|
|
|
|
|
|
|
(127
|
)
|
Cash and temporary cash investments
at beginning of period
|
|
|
322
|
|
|
|
|
|
|
|
542
|
|
|
|
|
|
|
|
864
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and temporary cash investments at end of
period
|
|
$
|
221
|
|
|
$
|
25
|
|
|
$
|
491
|
|
|
$
|
|
|
|
$
|
737
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
30
Item 2. Managements Discussion and Analysis of Financial Condition and Results of Operations
FORWARD-LOOKING STATEMENTS
This Form 10-Q, including without limitation the discussion below under the heading
Results of
Operations Outlook,
contains certain estimates, predictions, projections, assumptions and other
forward-looking statements (as defined in Section 27A of the Securities Act of 1933 and Section
21E of the Securities Exchange Act of 1934) that involve various risks and uncertainties. While
these forward-looking statements, and any assumptions upon which they are based, are made in good
faith and reflect Valeros current judgment regarding the direction of its business, actual results
will almost always vary, sometimes materially, from any estimates, predictions, projections,
assumptions or other future performance suggested in this report. These forward-looking statements
can generally be identified by the words anticipate, believe, expect, plan, intend,
estimate, project, budget, forecast, will, could, should, may and similar
expressions. These forward-looking statements include, among other things, statements regarding:
|
|
|
the synergies and accretion to reported earnings estimated to result from the merger of
Premcor into Valero (Premcor Acquisition) and level of costs and expenses to be incurred by
Valero in connection with the Premcor Acquisition;
|
|
|
|
various actions to be taken or requirements to be met in connection with integrating
Valero and Premcor after the Premcor Acquisition;
|
|
|
|
revenue, income and operations of Valero after the Premcor Acquisition;
|
|
|
|
future refining margins, including gasoline and distillate margins;
|
|
|
|
future retail margins, including gasoline, diesel, home heating oil and convenience
store merchandise margins;
|
|
|
|
expectations regarding feedstock costs, including crude oil discounts, and operating expenses;
|
|
|
|
anticipated levels of crude oil and refined product inventories;
|
|
|
|
Valeros anticipated level of capital investments, including deferred refinery
turnaround and catalyst costs and capital expenditures for environmental and other
purposes, and the effect of those capital investments on Valeros results of operations;
|
|
|
|
anticipated trends in the supply of and demand for crude oil and other feedstocks and
refined products in the United States, Canada and elsewhere;
|
|
|
|
expectations regarding environmental and other regulatory initiatives; and
|
|
|
|
the effect of general economic and other conditions on refining and retail industry
fundamentals.
|
Valeros forward-looking statements are based on its beliefs and assumptions derived from
information available at the time the statements are made. Differences between actual results and
any future performance suggested in these forward-looking statements could result from a variety of
factors, including the following:
|
|
|
expected cost savings from the Premcor Acquisition may not be fully realized or realized
within the expected time frame, and costs or expenses relating to the Premcor Acquisition
may be higher than expected;
|
|
|
|
revenues or margins following the Premcor Acquisition may be lower than expected;
|
|
|
|
costs or difficulties related to the integration of the businesses of Valero and Premcor
may be greater than expected;
|
|
|
|
acts of terrorism aimed at Valeros facilities or other facilities that could impair
Valeros ability to produce or transport refined products or receive feedstocks;
|
|
|
|
political and economic conditions in nations that consume refined products, including
the United States, and in crude oil producing regions, including the Middle East and South
America;
|
31
|
|
|
the domestic and foreign supplies of refined products such as gasoline, diesel fuel, jet
fuel, home heating oil and petrochemicals;
|
|
|
|
the domestic and foreign supplies of crude oil and other feedstocks;
|
|
|
|
the ability of the members of the Organization of Petroleum Exporting Countries to agree
on and to maintain crude oil price and production controls;
|
|
|
|
the level of consumer demand, including seasonal fluctuations;
|
|
|
|
refinery overcapacity or undercapacity;
|
|
|
|
the actions taken by competitors, including both pricing and the expansion and
retirement of refining capacity in response to market conditions;
|
|
|
|
environmental and other regulations at both the state and federal levels and in foreign
countries;
|
|
|
|
the level of foreign imports of refined products;
|
|
|
|
accidents or other unscheduled shutdowns affecting Valeros refineries, machinery,
pipelines or equipment, or those of Valeros suppliers or customers;
|
|
|
|
changes in the cost or availability of transportation for feedstocks and refined products;
|
|
|
|
the price, availability and acceptance of alternative fuels and alternative-fuel vehicles;
|
|
|
|
cancellation of or failure to implement planned capital projects and realize the various
assumptions and benefits projected for such projects or cost overruns in constructing such
planned capital projects;
|
|
|
|
earthquakes, hurricanes, tornadoes and irregular weather, which can unforeseeably affect
the price or availability of natural gas, crude oil and other feedstocks and refined
products;
|
|
|
|
rulings, judgments or settlements in litigation or other legal or regulatory matters,
including unexpected environmental remediation costs in excess of any reserves or insurance
coverage;
|
|
|
|
legislative or regulatory action, including the introduction or enactment of federal,
state or foreign legislation or rulemakings, which may adversely affect Valeros business
or operations;
|
|
|
|
changes in the credit ratings assigned to Valeros debt securities and trade credit;
|
|
|
|
changes in currency exchange rates, including the value of the Canadian dollar relative
to the U.S. dollar; and
|
|
|
|
overall economic conditions.
|
Any one of these factors, or a combination of these factors, could materially affect Valeros
future results of operations and whether any forward-looking statements ultimately prove to be
accurate. Valeros forward-looking statements are not guarantees of future performance, and actual
results and future performance may differ materially from those suggested in any forward-looking
statements. Valero does not intend to update these statements unless it is required by the
securities laws to do so.
All subsequent written and oral forward-looking statements attributable to Valero or persons acting
on its behalf are expressly qualified in their entirety by the foregoing. Valero undertakes no
obligation to publicly release the results of any revisions to any such forward-looking statements
that may be made to reflect events or circumstances after the date of this report or to reflect the
occurrence of unanticipated events.
32
Overview
As of September 30, 2005, Valero, an independent refining and marketing company, owned and operated
18 refineries in the United States, Canada and Aruba with a combined throughput capacity, including
crude oil and other feedstocks, of approximately 3.3 million barrels per day.
Valero markets refined products through an extensive bulk and rack marketing network and a network
of more than 4,700 retail and wholesale branded outlets in the United States, Canada and Aruba
under various brand names including primarily Valero
â
, Diamond Shamrock
â
,
Shamrock
â
, Ultramar
â
and Beacon
â
. During the second quarter of 2005, Valero
announced that it will retire the Diamond Shamrock brand and convert those U.S. retail and
wholesale sites to the Valero brand.
Valeros operations are affected by:
|
|
|
company-specific factors, primarily refinery utilization rates and refinery maintenance
turnarounds;
|
|
|
|
seasonal factors, such as the demand for refined products; and
|
|
|
|
industry factors, such as movements in and the level of crude oil prices including the
effect of quality differential between grades of crude oil, the demand for and prices of
refined products, industry supply capacity and competitor refinery maintenance turnarounds.
|
Valeros profitability is substantially determined by the spread between the price of refined
products and the price of crude oil, referred to as the refined product margin. Since nearly 65%
of Valeros total crude oil throughput represents sour crude oil and acidic sweet crude oil
feedstocks that are purchased at prices less than sweet crude oil, Valeros profitability is also
significantly affected by the spread between sweet crude oil and sour crude oil prices, referred to
as the sour crude oil discount. During the third quarter of 2005, Valero continued to benefit
from the same positive industry fundamentals experienced in the previous quarters of 2005. In
particular, gasoline and distillate margins rose sharply beginning in late August and continuing
through September due to the effect that Hurricanes Katrina and Rita had on the supply of these
refined products. Overall, gasoline and distillate margins more than doubled compared to the third
quarter of 2004. In addition, sour crude oil discounts improved in
the third quarter of 2005 compared to the already strong discounts
experienced in the third quarter of 2004. The sharp rise in gasoline and distillate margins
combined with the strong sour crude oil discounts contributed to a
significant increase in operating income in the third quarter of 2005
compared to the third quarter of 2004.
On September 1, 2005, Valero completed its merger with Premcor. Premcor owned and operated
refineries in Port Arthur, Texas; Lima, Ohio; Memphis, Tennessee; and Delaware City, Delaware, with
a combined crude oil throughput capacity of approximately 800,000 barrels per day. For the month
of September 2005, these four refineries generated approximately $330 million of operating income,
excluding the effect of a $621 million LIFO charge discussed below, and the Premcor Acquisition
contributed approximately $0.44 per share to Valeros earnings.
Operationally, the aftermath of Hurricane Katrina resulted in the shutdown of the St. Charles
Refinery for nine days and reduced production at the Krotz Springs, Ardmore, Lima and Memphis
Refineries. In late September, Hurricane Rita reduced operations at the Corpus Christi East and
West Refineries and ultimately shut down operations at the Houston, Texas City and Port Arthur
Refineries. The Port Arthur Refinery suffered damage from Hurricane Rita but resumed near-normal
operations in mid-October.
The positive industry fundamentals experienced during the third quarter and nine months ended
September 30, 2005, combined with the incremental income generated from the Premcor Acquisition,
resulted in net income for the third quarter of 2005 that was almost double the net income for the
third quarter of 2004, and net income for the nine months ended September 30, 2005 that was over
70% higher
33
than the net income reported for the nine months ended September 30, 2004. Valero reported net
income of $862 million, or $2.94 per share, for the third quarter of 2005, compared to $434
million, or $1.57 per share, for the third quarter of 2004, and net income of $2.2 billion, or
$7.92 per share, for the nine months ended September 30, 2005, compared to $1.3 billion, or $4.78
per share, for the nine months ended September 30, 2004. The reported net income for both the
third quarter and the nine months ended September 30, 2005 included the unfavorable effect of a
$621 million pre-tax LIFO charge related to the difference between the fair market value recorded
for the inventories acquired in the Premcor Acquisition under purchase accounting and the amounts
required to be recorded in applying Valeros LIFO accounting policy.
RESULTS OF OPERATIONS
Third Quarter 2005 Compared to Third Quarter 2004
Financial Highlights
(millions of dollars, except per share amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
|
2005 (a)
|
|
|
2004
|
|
|
Change
|
|
Operating revenues (b)
|
|
$
|
23,283
|
|
|
$
|
14,339
|
|
|
$
|
8,944
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales (a) (b)
|
|
|
20,638
|
|
|
|
12,683
|
|
|
|
7,955
|
|
Refining operating expenses
|
|
|
772
|
|
|
|
529
|
|
|
|
243
|
|
Retail selling expenses
|
|
|
201
|
|
|
|
177
|
|
|
|
24
|
|
General and administrative expenses
|
|
|
129
|
|
|
|
87
|
|
|
|
42
|
|
Depreciation and amortization expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining
|
|
|
187
|
|
|
|
140
|
|
|
|
47
|
|
Retail
|
|
|
22
|
|
|
|
14
|
|
|
|
8
|
|
Corporate
|
|
|
23
|
|
|
|
10
|
|
|
|
13
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
21,972
|
|
|
|
13,640
|
|
|
|
8,332
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
|
1,311
|
|
|
|
699
|
|
|
|
612
|
|
Equity in earnings of Valero L.P.
|
|
|
13
|
|
|
|
10
|
|
|
|
3
|
|
Other income, net
|
|
|
11
|
|
|
|
7
|
|
|
|
4
|
|
Interest and debt expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
Incurred
|
|
|
(85
|
)
|
|
|
(73
|
)
|
|
|
(12
|
)
|
Capitalized
|
|
|
18
|
|
|
|
10
|
|
|
|
8
|
|
|
|
|
|
|
|
|
|
|
|
Income before income tax expense
|
|
|
1,268
|
|
|
|
653
|
|
|
|
615
|
|
Income tax expense
|
|
|
406
|
|
|
|
219
|
|
|
|
187
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
|
862
|
|
|
|
434
|
|
|
|
428
|
|
Preferred stock dividends
|
|
|
4
|
|
|
|
3
|
|
|
|
1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income applicable to common stock
|
|
$
|
858
|
|
|
$
|
431
|
|
|
$
|
427
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per common share assuming dilution
|
|
$
|
2.94
|
|
|
$
|
1.57
|
|
|
$
|
1.37
|
|
See the footnote references on page 37.
34
Operating Highlights
(millions of dollars, except per barrel and per gallon amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
|
2005 (a)
|
|
|
2004
|
|
|
Change
|
|
Refining:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (a)
|
|
$
|
1,442
|
|
|
$
|
760
|
|
|
$
|
682
|
|
Throughput margin per barrel (c)
|
|
$
|
13.43
|
|
|
$
|
6.92
|
|
|
$
|
6.51
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
3.43
|
|
|
$
|
2.56
|
|
|
$
|
0.87
|
|
Depreciation and amortization
|
|
|
0.83
|
|
|
|
0.68
|
|
|
|
0.15
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
4.26
|
|
|
$
|
3.24
|
|
|
$
|
1.02
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Throughput volumes (thousand barrels per day):
|
|
|
|
|
|
|
|
|
|
|
|
|
Feedstocks:
|
|
|
|
|
|
|
|
|
|
|
|
|
Heavy sour crude
|
|
|
484
|
|
|
|
508
|
|
|
|
(24
|
)
|
Medium/light sour crude
|
|
|
579
|
|
|
|
635
|
|
|
|
(56
|
)
|
Acidic sweet crude
|
|
|
125
|
|
|
|
89
|
|
|
|
36
|
|
Sweet crude
|
|
|
668
|
|
|
|
507
|
|
|
|
161
|
|
Residuals
|
|
|
248
|
|
|
|
176
|
|
|
|
72
|
|
Other feedstocks
|
|
|
114
|
|
|
|
114
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total feedstocks
|
|
|
2,218
|
|
|
|
2,029
|
|
|
|
189
|
|
Blendstocks and other
|
|
|
227
|
|
|
|
214
|
|
|
|
13
|
|
|
|
|
|
|
|
|
|
|
|
Total throughput volumes
|
|
|
2,445
|
|
|
|
2,243
|
|
|
|
202
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Yields (thousand barrels per day):
|
|
|
|
|
|
|
|
|
|
|
|
|
Gasolines and blendstocks
|
|
|
1,165
|
|
|
|
1,050
|
|
|
|
115
|
|
Distillates
|
|
|
741
|
|
|
|
674
|
|
|
|
67
|
|
Petrochemicals
|
|
|
66
|
|
|
|
71
|
|
|
|
(5
|
)
|
Other products (d)
|
|
|
464
|
|
|
|
455
|
|
|
|
9
|
|
|
|
|
|
|
|
|
|
|
|
Total yields
|
|
|
2,436
|
|
|
|
2,250
|
|
|
|
186
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Retail U.S.:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
5
|
|
|
$
|
22
|
|
|
$
|
(17
|
)
|
Company-operated fuel sites (average)
|
|
|
1,029
|
|
|
|
1,103
|
|
|
|
(74
|
)
|
Fuel volumes (gallons per day per site)
|
|
|
4,966
|
|
|
|
4,787
|
|
|
|
179
|
|
Fuel margin per gallon
|
|
$
|
0.121
|
|
|
$
|
0.128
|
|
|
$
|
(0.007
|
)
|
Merchandise sales
|
|
$
|
250
|
|
|
$
|
247
|
|
|
$
|
3
|
|
Merchandise margin (percentage of sales)
|
|
|
30.1
|
%
|
|
|
27.8
|
%
|
|
|
2.3
|
%
|
Margin on miscellaneous sales
|
|
$
|
33
|
|
|
$
|
25
|
|
|
$
|
8
|
|
Retail selling expenses
|
|
$
|
145
|
|
|
$
|
127
|
|
|
$
|
18
|
|
Depreciation and amortization expense
|
|
$
|
16
|
|
|
$
|
8
|
|
|
$
|
8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Retail Northeast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
16
|
|
|
$
|
14
|
|
|
$
|
2
|
|
Fuel volumes (thousand gallons per day)
|
|
|
3,122
|
|
|
|
3,148
|
|
|
|
(26
|
)
|
Fuel margin per gallon
|
|
$
|
0.206
|
|
|
$
|
0.190
|
|
|
$
|
0.016
|
|
Merchandise sales
|
|
$
|
42
|
|
|
$
|
38
|
|
|
$
|
4
|
|
Merchandise margin (percentage of sales)
|
|
|
25.0
|
%
|
|
|
23.9
|
%
|
|
|
1.1
|
%
|
Margin on miscellaneous sales
|
|
$
|
8
|
|
|
$
|
7
|
|
|
$
|
1
|
|
Retail selling expenses
|
|
$
|
56
|
|
|
$
|
50
|
|
|
$
|
6
|
|
Depreciation and amortization expense
|
|
$
|
6
|
|
|
$
|
6
|
|
|
$
|
|
|
See the footnote references on page 37.
35
Refining Operating Highlights by Region (e)
(millions of dollars, except per barrel amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
|
2005 (a)
|
|
|
2004
|
|
|
Change
|
|
Gulf Coast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
1,163
|
|
|
$
|
488
|
|
|
$
|
675
|
|
Throughput volumes (thousand barrels per day) (f)
|
|
|
1,328
|
|
|
|
1,273
|
|
|
|
55
|
|
Throughput margin per barrel (c)
|
|
$
|
13.82
|
|
|
$
|
7.34
|
|
|
$
|
6.48
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
3.52
|
|
|
$
|
2.54
|
|
|
$
|
0.98
|
|
Depreciation and amortization
|
|
|
0.77
|
|
|
|
0.63
|
|
|
|
0.14
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
4.29
|
|
|
$
|
3.17
|
|
|
$
|
1.12
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Mid-Continent (g):
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
345
|
|
|
$
|
37
|
|
|
$
|
308
|
|
Throughput volumes (thousand barrels per day) (f)
|
|
|
352
|
|
|
|
291
|
|
|
|
61
|
|
Throughput margin per barrel (c)
|
|
$
|
14.85
|
|
|
$
|
4.77
|
|
|
$
|
10.08
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
3.39
|
|
|
$
|
2.71
|
|
|
$
|
0.68
|
|
Depreciation and amortization
|
|
|
0.80
|
|
|
|
0.64
|
|
|
|
0.16
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
4.19
|
|
|
$
|
3.35
|
|
|
$
|
0.84
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Northeast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
279
|
|
|
$
|
100
|
|
|
$
|
179
|
|
Throughput volumes (thousand barrels per day) (f)
|
|
|
451
|
|
|
|
381
|
|
|
|
70
|
|
Throughput margin per barrel (c)
|
|
$
|
10.27
|
|
|
$
|
5.33
|
|
|
$
|
4.94
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
2.79
|
|
|
$
|
1.89
|
|
|
$
|
0.90
|
|
Depreciation and amortization
|
|
|
0.76
|
|
|
|
0.59
|
|
|
|
0.17
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
3.55
|
|
|
$
|
2.48
|
|
|
$
|
1.07
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
West Coast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
276
|
|
|
$
|
135
|
|
|
$
|
141
|
|
Throughput volumes (thousand barrels per day)
|
|
|
314
|
|
|
|
298
|
|
|
|
16
|
|
Throughput margin per barrel (c)
|
|
$
|
14.78
|
|
|
$
|
9.29
|
|
|
$
|
5.49
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
4.00
|
|
|
$
|
3.40
|
|
|
$
|
0.60
|
|
Depreciation and amortization
|
|
|
1.22
|
|
|
|
1.00
|
|
|
|
0.22
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
5.22
|
|
|
$
|
4.40
|
|
|
$
|
0.82
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income for regions above
|
|
$
|
2,063
|
|
|
$
|
760
|
|
|
$
|
1,303
|
|
LIFO charge (see Note 5 in Condensed Notes to
Consolidated Financial Statements)
|
|
|
(621
|
)
|
|
|
|
|
|
|
(621
|
)
|
|
|
|
|
|
|
|
|
|
|
Total refining operating income
|
|
$
|
1,442
|
|
|
$
|
760
|
|
|
$
|
682
|
|
|
|
|
|
|
|
|
|
|
|
See the footnote references on page 37.
36
Average Market Reference Prices and Differentials (h)
(dollars per barrel)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30,
|
|
|
2005
|
|
2004
|
|
Change
|
Feedstocks:
|
|
|
|
|
|
|
|
|
|
|
|
|
West Texas Intermediate (WTI) crude oil
|
|
$
|
63.05
|
|
|
$
|
43.82
|
|
|
$
|
19.23
|
|
WTI less sour crude oil at U.S. Gulf Coast (i)
|
|
|
5.26
|
|
|
|
4.95
|
|
|
|
0.31
|
|
WTI less Alaska North Slope (ANS) crude oil
|
|
|
2.26
|
|
|
|
2.06
|
|
|
|
0.20
|
|
WTI less Maya crude oil
|
|
|
15.46
|
|
|
|
11.65
|
|
|
|
3.81
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Products:
|
|
|
|
|
|
|
|
|
|
|
|
|
U.S. Gulf Coast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Conventional 87 gasoline less WTI
|
|
|
19.38
|
|
|
|
7.24
|
|
|
|
12.14
|
|
No. 2 fuel oil less WTI
|
|
|
13.48
|
|
|
|
4.42
|
|
|
|
9.06
|
|
Propylene less WTI
|
|
|
(4.95
|
)
|
|
|
4.44
|
|
|
|
(9.39
|
)
|
U.S. Mid-Continent:
|
|
|
|
|
|
|
|
|
|
|
|
|
Conventional 87 gasoline less WTI
|
|
|
17.41
|
|
|
|
8.18
|
|
|
|
9.23
|
|
Low-sulfur diesel less WTI
|
|
|
16.35
|
|
|
|
7.89
|
|
|
|
8.46
|
|
U.S. Northeast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Conventional 87 gasoline less WTI
|
|
|
15.98
|
|
|
|
7.83
|
|
|
|
8.15
|
|
No. 2 fuel oil less WTI
|
|
|
12.47
|
|
|
|
5.29
|
|
|
|
7.18
|
|
Lube oils less WTI
|
|
|
32.32
|
|
|
|
21.40
|
|
|
|
10.92
|
|
U.S. West Coast:
|
|
|
|
|
|
|
|
|
|
|
|
|
CARBOB 87 gasoline less ANS
|
|
|
25.54
|
|
|
|
18.84
|
|
|
|
6.70
|
|
Low-sulfur diesel less ANS
|
|
|
24.56
|
|
|
|
15.77
|
|
|
|
8.79
|
|
|
|
|
The following notes relate to references on pages 34 through 37.
|
|
(a)
|
|
Includes the operations related to the Premcor Acquisition commencing on September 1, 2005.
Cost of sales and refining operating income presented for the three months ended September 30,
2005 include the effect of a $621 million LIFO charge related to the difference between the
fair market value recorded for the inventories acquired in the Premcor Acquisition under
purchase accounting and the amounts required to be recorded in applying Valeros LIFO
accounting policy. This charge was excluded from the consolidated and regional throughput
margins per barrel and the regional operating income amounts presented herein in order to make
the information presented comparable between periods.
|
|
(b)
|
|
Operating revenues and cost of sales both include approximately $2.3 billion for the three
months ended September 30, 2005, and approximately $1.3 billion for the three months ended
September 30, 2004, related to certain crude oil buy/sell arrangements, which involve linked
purchases and sales related to crude oil contracts entered into to address location, quality
or grade requirements. For further explanation of this accounting
treatment, see the explanation of EITF No. 04-13 in Note 2 of
Condensed Notes to Consolidated Financial Statements.
|
|
(c)
|
|
Throughput margin per barrel represents operating revenues less cost of sales divided by
throughput volumes.
|
|
(d)
|
|
Other products primarily include gas oils, No. 6 fuel oil, petroleum coke and asphalt.
|
|
(e)
|
|
The regions reflected herein contain the following refineries subsequent to the Premcor
Acquisition: the Gulf Coast refining region includes the Corpus Christi East, Corpus Christi
West, Texas City, Houston, Three Rivers, Krotz Springs, St. Charles, Aruba and Port Arthur
Refineries; the Mid-Continent refining region includes the McKee, Ardmore, Memphis and Lima
Refineries; the Northeast refining region includes the Quebec, Paulsboro and Delaware City
Refineries; and the West Coast refining region includes the Benicia and Wilmington Refineries.
|
|
(f)
|
|
Throughput volumes for the Gulf Coast, Mid-Continent and Northeast regions for the three
months ended September 30, 2005 include 66,000, 100,000 and 66,000 barrels per day,
respectively, related to the operations of the refineries acquired from Premcor commencing on
September 1, 2005. Throughput volumes for those acquired refineries for the 30 days of their
operations subsequent to the acquisition date of September 1, 2005 were 203,000, 306,000, and
203,000 barrels per day, respectively, for the Gulf Coast, Mid-Continent and Northeast
regions.
|
|
(g)
|
|
For the three months ended September 30, 2004, the information presented for the
Mid-Continent region includes the operations of the Denver Refinery, which was sold on May 31,
2005 to Suncor. Throughput volumes for the Mid-Continent region for the third quarter of 2004
include 38,000 barrels per day related to the Denver Refinery.
|
37
|
|
|
(h)
|
|
The average market reference prices and differentials, with the exception of the propylene and
lube oil differentials, are based on posted prices from Platts Oilgram. The propylene
differential is based on posted propylene prices in Chemical Market Associates, Inc. and the
lube oil differential is based on Exxon Mobil Corporation postings provided by Independent
Commodity Information Services-London Oil Reports. The average market reference prices and
differentials are presented to provide users of the consolidated financial statements with
economic indicators that significantly affect Valeros operations and profitability.
|
|
(i)
|
|
The market reference differential for sour crude oil is based on 50% Arab Medium and 50% Arab
Light posted prices.
|
General
Operating revenues increased 62% for the third quarter of 2005 compared to the third quarter of
2004 primarily as a result of significantly higher refined product prices combined with additional
throughput volumes from refinery operations. Operating income and net income for the three months
ended September 30, 2005 increased significantly compared to the three months ended September 30,
2004 despite the unfavorable impact in the third quarter of 2005 of a $621 million pre-tax, or
$1.43 per share, LIFO charge related to the difference between the fair market value recorded for
the inventories acquired in the Premcor Acquisition under purchase accounting and the amounts
required to be recorded in applying Valeros LIFO accounting policy. Operating income increased
$612 million, or 88%, and net income increased $428 million, or 99%, from the third quarter of 2004
to the third quarter of 2005 due primarily to a $682 million
increase in refining segment operating income, partially offset by a $55 million increase in general and administrative expenses (including
corporate depreciation and amortization expense) and a $15 million decrease in retail operating
income.
Refining
Operating income for Valeros refining segment increased from $760 million for the third quarter of
2004 to $1.4 billion for the third quarter of 2005, resulting from an increase in refining
throughput margin of $6.51 per barrel, or 94%, and an increase in throughput volumes due to the
acquisition of four refineries from Premcor on September 1, 2005. The increase in operating income
was partially offset by increased refining operating expenses (including depreciation and
amortization expense) of $290 million.
Refining total throughput margin for the third quarter of 2005 increased primarily due to the
following factors:
|
|
|
Gasoline and distillate margins increased significantly in all of Valeros refining
regions in the third quarter of 2005 compared to the third quarter of 2004, more than
doubling in three of the four regions. The higher refined product margins for the third
quarter of 2005 were primarily due to the impact of Hurricanes Katrina and Rita, which
reduced the supply of refined products as refineries along the Gulf Coast reduced or shut
down their operations in anticipation of the hurricanes.
|
|
|
|
Discounts on Valeros sour crude oil feedstocks during the third quarter of 2005
increased compared to the third quarter of 2004 due to ample supplies of sour crude oils
and heavy sour residual fuel oils on the world market. In addition, discounts on sour
crude oil feedstocks continued to benefit from increased demand for sweet crude oil
resulting from several factors, including (i) the global movement to cleaner fuels, which
has required most refineries to lower the sulfur content of the gasoline they produce, and
(ii) a global increase in refined product demand, particularly in Asia, which has resulted
in higher utilization rates by refineries that require sweet crude oil as feedstock.
|
|
|
|
Throughput volumes increased 202,000 barrels per day in the third quarter of 2005
compared to the third quarter of 2004 due to the incremental throughput from the four
refineries acquired from Premcor on September 1, 2005.
|
38
Partially offsetting the above increases in throughput margin were lower margins on other refined
products such as petroleum coke, sulfur, No. 6 fuel oil, asphalt and propylene due to a significant
increase in the price of crude oil from the third quarter of 2004 to the third quarter of 2005.
Refining operating expenses were 46% higher for the quarter ended September 30, 2005 compared to
the quarter ended September 30, 2004, due primarily to the Premcor Acquisition on September 1,
2005, higher energy costs and increases in maintenance expense, insurance expense, catalyst and
chemicals, and professional fees and outside services. Refining depreciation and amortization
expense increased 34% from the third quarter of 2004 to the third quarter of 2005 primarily due to
increased turnaround and catalyst amortization, the Premcor Acquisition, the implementation of new
capital projects and the write-off of costs in 2005 resulting from the decision to rebrand
wholesale sites marketing under the Diamond Shamrock brand to the Valero brand.
Retail
Retail operating income was $21 million for the quarter ended September 30, 2005 compared to $36
million for the quarter ended September 30, 2004. The decrease was attributable primarily to
increased selling expenses in Valeros U.S. retail operations mainly as a result of higher credit
card processing fees attributable to higher retail fuel prices.
Corporate Expenses and Other
General and administrative expenses, including corporate depreciation and amortization expense,
increased $55 million from the third quarter of 2004 to the third quarter of 2005. The increase
was primarily due to the Premcor Acquisition on September 1, 2005 and increases in employee
compensation and benefits of approximately $36 million between the quarters, mainly related to the
recognition of increased variable compensation expense.
Interest and debt expense incurred increased $12 million from the third quarter of 2004 to the
third quarter of 2005 primarily as a result of additional debt incurred to fund the Premcor
Acquisition and interest expense incurred on the debt assumed in the Premcor Acquisition.
Income tax expense increased $187 million from the third quarter of 2004 to the third quarter of
2005 mainly as a result of higher operating income. Valeros effective tax rate for the quarter
ended September 30, 2005 decreased from the quarter ended September 30, 2004 as a higher percentage
of Valeros pre-tax income was contributed by the Aruba Refinery, the operations of which are
non-taxable in Aruba through December 31, 2010.
39
Nine Months Ended September 30, 2005 Compared to Nine Months Ended September 30, 2004
Financial Highlights
(millions of dollars, except per share amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
2005 (a)
|
|
|
2004 (b)
|
|
|
Change
|
|
Operating revenues (c)
|
|
$
|
56,268
|
|
|
$
|
39,228
|
|
|
$
|
17,040
|
|
|
|
|
|
|
|
|
|
|
|
|
Costs and expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales (a) (c)
|
|
|
49,389
|
|
|
|
34,260
|
|
|
|
15,129
|
|
Refining operating expenses
|
|
|
1,938
|
|
|
|
1,553
|
|
|
|
385
|
|
Retail selling expenses
|
|
|
561
|
|
|
|
518
|
|
|
|
43
|
|
General and administrative expenses
|
|
|
303
|
|
|
|
263
|
|
|
|
40
|
|
Depreciation and amortization expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining
|
|
|
504
|
|
|
|
392
|
|
|
|
112
|
|
Retail
|
|
|
59
|
|
|
|
42
|
|
|
|
17
|
|
Corporate
|
|
|
52
|
|
|
|
30
|
|
|
|
22
|
|
|
|
|
|
|
|
|
|
|
|
Total costs and expenses
|
|
|
52,806
|
|
|
|
37,058
|
|
|
|
15,748
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
|
3,462
|
|
|
|
2,170
|
|
|
|
1,292
|
|
Equity in earnings of Valero L.P.
|
|
|
32
|
|
|
|
29
|
|
|
|
3
|
|
Other income (expense), net
|
|
|
(4
|
)
|
|
|
4
|
|
|
|
(8
|
)
|
Interest and debt expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
Incurred
|
|
|
(230
|
)
|
|
|
(222
|
)
|
|
|
(8
|
)
|
Capitalized
|
|
|
39
|
|
|
|
27
|
|
|
|
12
|
|
|
|
|
|
|
|
|
|
|
|
Income before income tax expense
|
|
|
3,299
|
|
|
|
2,008
|
|
|
|
1,291
|
|
Income tax expense
|
|
|
1,056
|
|
|
|
693
|
|
|
|
363
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
|
2,243
|
|
|
|
1,315
|
|
|
|
928
|
|
Preferred stock dividends
|
|
|
12
|
|
|
|
9
|
|
|
|
3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income applicable to common stock
|
|
$
|
2,231
|
|
|
$
|
1,306
|
|
|
$
|
925
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per common share assuming dilution
|
|
$
|
7.92
|
|
|
$
|
4.78
|
|
|
$
|
3.14
|
|
See the footnote references on page 43.
40
Operating Highlights
(millions of dollars, except per barrel and per gallon amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
2005 (a)
|
|
|
2004 (b)
|
|
|
Change
|
|
Refining:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income (a)
|
|
$
|
3,739
|
|
|
$
|
2,341
|
|
|
$
|
1,398
|
|
Throughput margin per barrel (d)
|
|
$
|
10.80
|
|
|
$
|
7.31
|
|
|
$
|
3.49
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
3.08
|
|
|
$
|
2.65
|
|
|
$
|
0.43
|
|
Depreciation and amortization
|
|
|
0.80
|
|
|
|
0.67
|
|
|
|
0.13
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
3.88
|
|
|
$
|
3.32
|
|
|
$
|
0.56
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Throughput volumes (thousand barrels per day) (e):
|
|
|
|
|
|
|
|
|
|
|
|
|
Feedstocks:
|
|
|
|
|
|
|
|
|
|
|
|
|
Heavy sour crude
|
|
|
495
|
|
|
|
472
|
|
|
|
23
|
|
Medium/light sour crude
|
|
|
582
|
|
|
|
564
|
|
|
|
18
|
|
Acidic sweet crude
|
|
|
112
|
|
|
|
100
|
|
|
|
12
|
|
Sweet crude
|
|
|
591
|
|
|
|
534
|
|
|
|
57
|
|
Residuals
|
|
|
183
|
|
|
|
127
|
|
|
|
56
|
|
Other feedstocks
|
|
|
124
|
|
|
|
133
|
|
|
|
(9
|
)
|
|
|
|
|
|
|
|
|
|
|
Total feedstocks
|
|
|
2,087
|
|
|
|
1,930
|
|
|
|
157
|
|
Blendstocks and other
|
|
|
220
|
|
|
|
208
|
|
|
|
12
|
|
|
|
|
|
|
|
|
|
|
|
Total throughput volumes
|
|
|
2,307
|
|
|
|
2,138
|
|
|
|
169
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Yields (thousand barrels per day):
|
|
|
|
|
|
|
|
|
|
|
|
|
Gasolines and blendstocks
|
|
|
1,086
|
|
|
|
1,036
|
|
|
|
50
|
|
Distillates
|
|
|
697
|
|
|
|
638
|
|
|
|
59
|
|
Petrochemicals
|
|
|
67
|
|
|
|
70
|
|
|
|
(3
|
)
|
Other products (f)
|
|
|
459
|
|
|
|
402
|
|
|
|
57
|
|
|
|
|
|
|
|
|
|
|
|
Total yields
|
|
|
2,309
|
|
|
|
2,146
|
|
|
|
163
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Retail U.S.:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
21
|
|
|
$
|
56
|
|
|
$
|
(35
|
)
|
Company-operated fuel sites (average)
|
|
|
1,029
|
|
|
|
1,123
|
|
|
|
(94
|
)
|
Fuel volumes (gallons per day per site)
|
|
|
4,862
|
|
|
|
4,640
|
|
|
|
222
|
|
Fuel margin per gallon
|
|
$
|
0.118
|
|
|
$
|
0.128
|
|
|
$
|
(0.010
|
)
|
Merchandise sales
|
|
$
|
710
|
|
|
$
|
705
|
|
|
$
|
5
|
|
Merchandise margin (percentage of sales)
|
|
|
29.7
|
%
|
|
|
28.3
|
%
|
|
|
1.4
|
%
|
Margin on miscellaneous sales
|
|
$
|
91
|
|
|
$
|
73
|
|
|
$
|
18
|
|
Retail selling expenses
|
|
$
|
400
|
|
|
$
|
374
|
|
|
$
|
26
|
|
Depreciation and amortization expense
|
|
$
|
42
|
|
|
$
|
26
|
|
|
$
|
16
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Retail Northeast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
57
|
|
|
$
|
66
|
|
|
$
|
(9
|
)
|
Fuel volumes (thousand gallons per day)
|
|
|
3,192
|
|
|
|
3,234
|
|
|
|
(42
|
)
|
Fuel margin per gallon
|
|
$
|
0.210
|
|
|
$
|
0.209
|
|
|
$
|
0.001
|
|
Merchandise sales
|
|
$
|
112
|
|
|
$
|
103
|
|
|
$
|
9
|
|
Merchandise margin (percentage of sales)
|
|
|
25.4
|
%
|
|
|
24.1
|
%
|
|
|
1.3
|
%
|
Margin on miscellaneous sales
|
|
$
|
23
|
|
|
$
|
17
|
|
|
$
|
6
|
|
Retail selling expenses
|
|
$
|
161
|
|
|
$
|
144
|
|
|
$
|
17
|
|
Depreciation and amortization expense
|
|
$
|
17
|
|
|
$
|
16
|
|
|
$
|
1
|
|
See the footnote references on page 43.
41
Refining Operating Highlights by Region (g)
(millions of dollars, except per barrel amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
|
2005 (a)
|
|
|
2004 (b)
|
|
|
Change
|
|
Gulf Coast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
2,616
|
|
|
$
|
1,337
|
|
|
$
|
1,279
|
|
Throughput volumes (thousand barrels per day)
(e) (h)
|
|
|
1,289
|
|
|
|
1,185
|
|
|
|
104
|
|
Throughput margin per barrel (d)
|
|
$
|
11.17
|
|
|
$
|
7.40
|
|
|
$
|
3.77
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
3.01
|
|
|
$
|
2.65
|
|
|
$
|
0.36
|
|
Depreciation and amortization
|
|
|
0.72
|
|
|
|
0.64
|
|
|
|
0.08
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
3.73
|
|
|
$
|
3.29
|
|
|
$
|
0.44
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
MidContinent (i):
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
492
|
|
|
$
|
212
|
|
|
$
|
280
|
|
Throughput volumes (thousand barrels per day) (h)
|
|
|
302
|
|
|
|
292
|
|
|
|
10
|
|
Throughput margin per barrel (d)
|
|
$
|
9.93
|
|
|
$
|
5.88
|
|
|
$
|
4.05
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
3.27
|
|
|
$
|
2.65
|
|
|
$
|
0.62
|
|
Depreciation and amortization
|
|
|
0.70
|
|
|
|
0.58
|
|
|
|
0.12
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
3.97
|
|
|
$
|
3.23
|
|
|
$
|
0.74
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Northeast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
501
|
|
|
$
|
358
|
|
|
$
|
143
|
|
Throughput volumes (thousand barrels per day) (h)
|
|
|
406
|
|
|
|
377
|
|
|
|
29
|
|
Throughput margin per barrel (d)
|
|
$
|
7.88
|
|
|
$
|
5.92
|
|
|
$
|
1.96
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
2.58
|
|
|
$
|
1.87
|
|
|
$
|
0.71
|
|
Depreciation and amortization
|
|
|
0.79
|
|
|
|
0.58
|
|
|
|
0.21
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
3.37
|
|
|
$
|
2.45
|
|
|
$
|
0.92
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
West Coast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
$
|
751
|
|
|
$
|
434
|
|
|
$
|
317
|
|
Throughput volumes (thousand barrels per day)
|
|
|
310
|
|
|
|
284
|
|
|
|
26
|
|
Throughput margin per barrel (d)
|
|
$
|
13.94
|
|
|
$
|
10.25
|
|
|
$
|
3.69
|
|
Operating costs per barrel:
|
|
|
|
|
|
|
|
|
|
|
|
|
Refining operating expenses
|
|
$
|
3.81
|
|
|
$
|
3.69
|
|
|
$
|
0.12
|
|
Depreciation and amortization
|
|
|
1.24
|
|
|
|
1.00
|
|
|
|
0.24
|
|
|
|
|
|
|
|
|
|
|
|
Total operating costs per barrel
|
|
$
|
5.05
|
|
|
$
|
4.69
|
|
|
$
|
0.36
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income for regions above
|
|
$
|
4,360
|
|
|
$
|
2,341
|
|
|
$
|
2,019
|
|
LIFO charge (see Note 5 in Condensed Notes to
Consolidated Financial Statements)
|
|
|
(621
|
)
|
|
|
|
|
|
|
(621
|
)
|
|
|
|
|
|
|
|
|
|
|
Total refining operating income
|
|
$
|
3,739
|
|
|
$
|
2,341
|
|
|
$
|
1,398
|
|
|
|
|
|
|
|
|
|
|
|
See the footnote references on page 43.
42
Average Market Reference Prices and Differentials (j)
(dollars per barrel)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30,
|
|
|
2005
|
|
2004
|
|
Change
|
Feedstocks:
|
|
|
|
|
|
|
|
|
|
|
|
|
WTI crude oil
|
|
$
|
55.26
|
|
|
$
|
39.13
|
|
|
$
|
16.13
|
|
WTI less sour crude oil at U.S. Gulf Coast (k)
|
|
|
6.68
|
|
|
|
4.54
|
|
|
|
2.14
|
|
WTI less ANS crude oil
|
|
|
3.36
|
|
|
|
1.49
|
|
|
|
1.87
|
|
WTI less Maya crude oil
|
|
|
15.20
|
|
|
|
9.91
|
|
|
|
5.29
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Products:
|
|
|
|
|
|
|
|
|
|
|
|
|
U.S. Gulf Coast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Conventional 87 gasoline less WTI
|
|
|
11.63
|
|
|
|
9.47
|
|
|
|
2.16
|
|
No. 2 fuel oil less WTI
|
|
|
10.15
|
|
|
|
2.89
|
|
|
|
7.26
|
|
Propylene less WTI
|
|
|
6.61
|
|
|
|
7.76
|
|
|
|
(1.15
|
)
|
U.S. Mid-Continent:
|
|
|
|
|
|
|
|
|
|
|
|
|
Conventional 87 gasoline less WTI
|
|
|
11.70
|
|
|
|
10.29
|
|
|
|
1.41
|
|
Low-sulfur diesel less WTI
|
|
|
13.09
|
|
|
|
6.07
|
|
|
|
7.02
|
|
U.S. Northeast:
|
|
|
|
|
|
|
|
|
|
|
|
|
Conventional 87 gasoline less WTI
|
|
|
9.60
|
|
|
|
9.62
|
|
|
|
(0.02
|
)
|
No. 2 fuel oil less WTI
|
|
|
10.80
|
|
|
|
4.01
|
|
|
|
6.79
|
|
Lube oils less WTI
|
|
|
29.74
|
|
|
|
23.27
|
|
|
|
6.47
|
|
U.S. West Coast:
|
|
|
|
|
|
|
|
|
|
|
|
|
CARBOB 87 gasoline less ANS
|
|
|
22.04
|
|
|
|
20.44
|
|
|
|
1.60
|
|
Low-sulfur diesel less ANS
|
|
|
20.94
|
|
|
|
14.90
|
|
|
|
6.04
|
|
|
|
|
The following notes relate to references on pages 40 through 43.
|
|
(a)
|
|
Includes the operations related to the Premcor Acquisition commencing on September 1, 2005.
Cost of sales and refining operating income presented for the nine months ended September 30,
2005 include the effect of a $621 million LIFO charge related to the difference between the
fair market value recorded for the inventories acquired in the Premcor Acquisition under
purchase accounting and the amounts required to be recorded in applying Valeros LIFO
accounting policy. This charge was excluded from the consolidated and regional throughput
margins per barrel and the regional operating income amounts presented herein in order to make
the information presented comparable between periods.
|
|
(b)
|
|
Includes the operations related to the Aruba Acquisition commencing on March 5, 2004.
|
|
(c)
|
|
Operating revenues and cost of sales both include approximately $5.1 billion for the nine
months ended September 30, 2005, and approximately $3.5 billion for the nine months ended
September 30, 2004, related to certain crude oil buy/sell arrangements, which involve linked
purchases and sales related to crude oil contracts entered into to address location, quality
or grade requirements. For further explanation of this accounting
treatment, see the explanation of EITF No. 04-13 in Note 2 of
Condensed Notes to Consolidated Financial Statements.
|
|
(d)
|
|
Throughput margin per barrel represents operating revenues less cost of sales divided by
throughput volumes.
|
|
(e)
|
|
Total throughput volumes and throughput volumes for the Gulf Coast region for the nine months
ended September 30, 2005 and 2004 are based on 273 days and 274 days, respectively, which
results in 221,000 barrels per day and 170,000 barrels per day being included for the Aruba
Refinery for the nine months ended September 30, 2005 and 2004, respectively. Throughput
volumes for the Aruba Refinery for the 210 days of its operations during the first nine months
of 2004 averaged 222,000 barrels per day.
|
|
(f)
|
|
Other products primarily include gas oils, No. 6 fuel oil, petroleum coke and asphalt.
|
|
(g)
|
|
The regions reflected herein contain the following refineries subsequent to the Premcor
Acquisition: the Gulf Coast refining region includes the Corpus Christi East, Corpus Christi
West, Texas City, Houston, Three Rivers, Krotz Springs, St. Charles, Aruba and Port Arthur
Refineries; the Mid-Continent refining region includes the McKee, Ardmore, Memphis and Lima
Refineries; the Northeast refining region includes the Quebec, Paulsboro and Delaware City
Refineries; and the West Coast refining region includes the Benicia and Wilmington Refineries.
|
43
|
|
|
(h)
|
|
Throughput volumes for the Gulf Coast, Mid-Continent and Northeast regions for the nine months
ended September 30, 2005 include 22,000, 34,000, and 22,000 barrels per day, respectively,
related to the operations of the refineries acquired from Premcor commencing on September 1,
2005. Throughput volumes for those acquired refineries for the 30 days of their operations
subsequent to the acquisition date of September 1, 2005 were 203,000, 306,000, and 203,000
barrels per day, respectively, for the Gulf Coast, Mid-Continent and Northeast regions.
|
|
(i)
|
|
The information presented for the Mid-Continent region includes the operations of the Denver
Refinery through May 31, 2005, the date of Valeros sale of this facility to Suncor.
Throughput volumes for the Mid-Continent region include 21,000 and 37,000 barrels per day
related to the Denver Refinery for the nine months ended September 30, 2005 and 2004,
respectively.
|
|
(j)
|
|
The average market reference prices and differentials, with the exception of the propylene
and lube oil differentials, are based on posted prices from Platts Oilgram. The propylene
differential is based on posted propylene prices in Chemical Market Associates, Inc. and the
lube oil differential is based on Exxon Mobil Corporation postings provided by Independent
Commodity Information Services-London Oil Reports. The average market reference prices and
differentials are presented to provide users of the consolidated financial statements with
economic indicators that significantly affect Valeros operations and profitability.
|
|
(k)
|
|
The market reference differential for sour crude oil is based on 50% Arab Medium and 50% Arab
Light posted prices.
|
General
Operating revenues increased 43% for the nine months ended September 30, 2005 compared to the nine
months ended September 30, 2004 primarily as a result of significantly higher refined product
prices combined with additional throughput volumes from refinery operations. Operating income and
net income for the nine months ended September 30, 2005 increased significantly compared to the
nine months ended September 30, 2004 despite the unfavorable impact in the 2005 period of a $621
million pre-tax LIFO charge related to the difference between the fair market value recorded for
the inventories acquired in the Premcor Acquisition under purchase accounting and the amounts
required to be recorded in applying Valeros LIFO accounting policy. Operating income increased
$1.3 billion, or 60%, from the first nine months of 2004 to the first nine months of 2005 due
primarily to a $1.4 billion increase in the refining segment, partially offset by a $44 million
decrease in the retail segment and a $62 million increase in general and administrative expenses
(including corporate depreciation and amortization expense).
Refining
Operating income for Valeros refining segment increased from $2.3 billion for the nine months
ended September 30, 2004 to $3.7 billion for the nine months ended September 30, 2005, resulting
from an increase in refining throughput margin of $3.49 per barrel, or 48%, and an 8% increase in
throughput volumes, partially offset by an increase in refining operating expenses (including
depreciation and amortization expense) of $497 million.
Refining total throughput margin for the first nine months of 2005 increased primarily due to the
following factors:
|
|
|
Distillate margins increased significantly in all of Valeros refining regions in the
first nine months of 2005 compared to the first nine months of 2004 due to increased
foreign and U.S. demand, which resulted specifically from improved economies and higher
demand for on-road diesel and jet fuel. In addition, both gasoline and distillate margins
increased significantly in September of 2005 due to the impact of Hurricanes Katrina and
Rita, which reduced the supply of refined products as refineries along the Gulf Coast
reduced or shut down their operations in anticipation of the hurricanes.
|
|
|
|
Discounts on Valeros sour crude oil feedstocks during the first nine months of 2005
increased compared to the first nine months of 2004 due to ample supplies of sour crude
oils and heavy sour residual fuel oils on the world market. In addition, discounts on sour
crude oil feedstocks benefited from increased demand for sweet crude oil resulting from
several factors, including (i) the global movement to cleaner fuels, which has required
most refineries to lower the sulfur
|
44
|
|
|
content of the gasoline they produce, and (ii) a global increase in refined product demand,
particularly in Asia, which has resulted in higher utilization rates by refineries that
require sweet crude oil as feedstock.
|
|
|
|
Throughput volumes increased 169,000 barrels per day in the first nine months of 2005
compared to the first nine months of 2004 due to throughput of 78,000 barrels per day at
the four refineries acquired from Premcor on September 1, 2005, incremental throughput of
51,000 barrels per day at the Aruba Refinery, which was acquired in March 2004, and lower
volumes in the first nine months of 2004 due to turnarounds at the St. Charles and
Wilmington Refineries.
|
Partially offsetting the above increases in throughput margin were lower margins on other refined
products such as petroleum coke, sulfur, No. 6 fuel oil, asphalt and propylene due to a significant
increase in the price of crude oil from the first nine months of 2004 to the first nine months of
2005. In addition, Valeros throughput margin in the first nine months of 2005 was negatively
impacted by pre-tax losses of approximately $360 million on hedges related to forward sales of
distillates and associated forward purchases of crude oil, the majority of which were entered into
during 2004.
Refining operating expenses were 25% higher for the nine months ended September 30, 2005 compared
to the nine months ended September 30, 2004, due to expenses related to the Premcor Acquisition, a
full nine months of operations of the Aruba Refinery and increases in energy costs, employee
compensation expense, including variable compensation, insurance expense, and maintenance expense.
Refining depreciation and amortization expense increased 29% from the first nine months of 2004 to
the first nine months of 2005 due to depreciation expense resulting from the Premcor Acquisition on
September 1, 2005, increased turnaround and catalyst amortization, implementation of new capital
projects, and the write-off of costs in 2005 resulting from the decision to rebrand wholesale sites
marketing under the Diamond Shamrock brand to the Valero brand.
Retail
Retail operating income was $78 million for the nine months ended September 30, 2005 compared to
$122 million for the nine months ended September 30, 2004, a decrease of 36% between the periods.
The decrease was primarily attributable to lower fuel margins and higher selling expenses in the
U.S. The increase in selling expenses was mainly due to higher credit card processing fees
resulting from higher retail fuel prices.
Corporate Expenses and Other
General and administrative expenses, including corporate depreciation and amortization expense,
increased $62 million for the nine months ended September 30, 2005 compared to the nine months
ended September 30, 2004, primarily due to increases in employee compensation and benefits, mainly
related to the recognition of increased variable compensation expense, and incremental expense due
to the Premcor Acquisition. These increases were partially offset by the successful resolution in
the first quarter of 2005 of a California excise tax dispute and reduced systems-related costs.
The decrease in other income (expense), net of $8 million for the first nine months of 2005
compared to the first nine months of 2004 was due mainly to Valeros 50% interest in certain debt
refinancing costs incurred in June 2005 by the Cameron Highway Oil Pipeline joint venture and an
increase in costs related to Valeros accounts receivable sales program, partially offset by an
increase in bank interest income due to higher cash balances.
Income tax expense increased $363 million from the first nine months of 2004 to the first nine
months of 2005 mainly as a result of higher operating income. Valeros effective tax rate for the
nine months ended
45
September 30, 2005 decreased from the nine months ended September 30, 2004 as a higher percentage
of Valeros pre-tax income was contributed by the Aruba Refinery, the operations of which are
non-taxable in Aruba through December 31, 2010.
OUTLOOK
For the fourth quarter of 2005, Valero expects that the same positive industry fundamentals
experienced throughout 2005 will continue. Distillate margins to date in the fourth quarter have
been in excess of the very strong margins experienced in the third quarter of 2005 and are expected
to remain strong due to lost production from the hurricanes, the upcoming winter weather and strong
global demand. Gasoline margins thus far in the fourth quarter have been above average for this
time of year due to lower-than-historical inventory levels. Gasoline demand declined near the end
of the third quarter due to higher retail pump prices attributable to the hurricanes in August and
September. However, as more refineries have come back in service, pump prices have declined and
gasoline demand has recovered to levels at or above the demand experienced in the latter part of
2004. Sour crude oil discounts have risen in the fourth quarter from third quarter levels, similar
to the increase experienced in the fourth quarter of 2004. Valero expects that increasing winter
demand for crude oil will result in incremental supplies of heavy sour crude oil, and the limited
global capacity to process such sour crude oil should lead to wider sour crude oil discounts.
These factors, combined with the additional throughput volumes from the Premcor Acquisition and the
completion of various capital improvement projects, should have a positive impact on Valeros
results of operations for the fourth quarter of 2005.
LIQUIDITY AND CAPITAL RESOURCES
Cash Flows for the Nine Months Ended September 30, 2005 and 2004
Net cash provided by operating activities for the nine months ended September 30, 2005 was $3.8
billion compared to $1.9 billion for the nine months ended September 30, 2004. The increase in
cash generated from operating activities was due primarily to the significant increase in operating
income discussed above under Results of Operations. Changes in cash provided by or used for
working capital during the first nine months of 2005 and 2004 are shown in Note 10 of Condensed
Notes to Consolidated Financial Statements. Significant changes for both periods resulted from an
increase in commodity prices during each respective period and an increased accrual for income tax
payments due to the significant income earned in the first nine months of 2005 and 2004. In
addition, working capital for the nine months ended September 30, 2004 was impacted by an increase
in the level of Valeros inventories and increased accrued expenses resulting from derivative
transactions and interest accruals.
The net cash generated from operating activities during the first nine months of 2005, combined
with $1.5 billion of proceeds from debt borrowings, $146 million of proceeds from the issuance of
common stock related to Valeros benefit plans, $127 million of available cash on hand, $45 million
of proceeds from the sale of the Denver Refinery as discussed in Note 3 of Condensed Notes to
Consolidated Financial Statements, and a $40 million net return of investment from the Cameron
Highway Oil Pipeline joint venture resulting from the refinancing of the joint ventures debt in
June 2005, were used mainly to:
|
|
|
fund $2.3 billion of the Premcor Acquisition, net of cash acquired,
|
|
|
|
fund $1.6 billion of capital expenditures and deferred turnaround and catalyst costs,
|
|
|
|
make debt repayments of $1.4 billion,
|
|
|
|
purchase 2.9 million shares of treasury stock at a cost of $188 million,
|
|
|
|
fund contingent earn-out payments in connection with the acquisition of Basis Petroleum,
Inc. and the St. Charles Acquisition of $35 million and $50 million, respectively,
|
46
|
|
|
fund certain minor acquisitions for $62 million,
|
|
|
|
make a general partner contribution to Valero L.P. of $29 million, and
|
|
|
|
pay common and preferred stock dividends of $75 million.
|
As discussed above, net cash provided by operating activities during the first nine months of 2004
was $1.9 billion. The net cash provided by operations, combined with $406 million of proceeds from
the sale of common stock, $333 million of net borrowings (net of debt repayments), $112 million of
proceeds from the issuance of common stock related to Valeros benefit plans and $58 million of
proceeds from the disposition of property, plant and equipment, were used mainly to:
|
|
|
fund $1.0 billion of capital expenditures and deferred turnaround and catalyst costs,
|
|
|
|
exercise options under structured lease arrangements to purchase $567 million of leased
property,
|
|
|
|
fund the Aruba Acquisition of $548 million, net of cash acquired,
|
|
|
|
purchase 8.0 million shares of treasury stock at a cost of $245 million,
|
|
|
|
fund contingent payments in connection with acquisitions of $53 million, and
|
|
|
|
pay common and preferred stock dividends of $58 million.
|
Capital Investments
On September 1, 2005, Valero completed its merger with Premcor. Valero paid the cash portion of
the merger consideration from available cash and a $1.5 billion five-year bank term loan due in
August 2010 (see Note 7 of Condensed Notes to Consolidated Financial Statements for additional
details related to the $1.5 billion term loan). In addition, Valero assumed Premcors existing
debt, which had a fair value of $1.9 billion as of September 1, 2005.
During the nine months ended September 30, 2005, Valero expended $1.3 billion for capital
expenditures and $262 million for deferred turnaround and catalyst costs. Capital expenditures for
the nine months ended September 30, 2005 included approximately $615 million of costs related to
environmental projects.
In connection with Valeros acquisitions of Basis Petroleum, Inc. in 1997 and the St. Charles
Refinery in 2003, the sellers are entitled to receive payments in any of the ten years and seven
years, respectively, following these acquisitions if certain average refining margins during any of
those years exceed a specified level. In connection with the Premcor Acquisition, Valero assumed
Premcors obligation under an earn-out contingency agreement related to Premcors acquisition of
the Delaware City Refinery from Motiva. Under this agreement, Motiva is entitled to receive two
separate annual earn-out contingency payments depending on (a) the amount of crude oil processed at
the refinery and the level of refining margins through May 2007, and (b) the achievement of certain
performance criteria at the gasification facility through May 2006.
Any payments due under these earn-out arrangements are limited based on annual and aggregate
limits. In January 2005, Valero made an earn-out payment of $50 million related to the acquisition
of the St. Charles Refinery. In May 2005, Valero made an earn-out payment of $35 million to
Salomon Inc in connection with Valeros acquisition of Basis Petroleum, Inc. Based on actual
margin levels through October 2005 and estimated margin levels for November and December 2005, the
annual maximum earn-out payment of $50 million for the St. Charles Refinery would be due for the
year ending December 2005 and would be payable in early 2006.
For 2005, Valero expects to incur approximately $2.6 billion for capital investments, including
approximately $2.2 billion for capital expenditures (approximately $1.1 billion of which is for
environmental projects) and approximately $400 million for deferred turnaround and catalyst costs.
The capital expenditure estimate includes anticipated expenditures related to the four refineries
acquired in the
47
Premcor Acquisition and excludes anticipated expenditures related to the earn-out contingency
agreements discussed above and strategic acquisitions. Valero continuously evaluates its capital
budget and makes changes as economic conditions warrant.
Valero expects to incur approximately $70 million related to the conversion of U.S. retail and
wholesale sites from the Diamond Shamrock brand to the Valero brand. These conversions are
expected to be substantially complete by early 2007. As of September 30, 2005, approximately $5
million has been incurred.
Contractual Obligations
As of September 30, 2005, Valeros contractual obligations included long-term debt, capital lease
obligations, operating leases and purchase obligations. As a result of the consummation of the
Premcor Acquisition on September 1, 2005, there were significant changes to Valeros contractual
obligations during the nine months ended September 30, 2005. In conjunction with the Premcor
Acquisition, Valero assumed debt with a fair value of $1.9 billion and $14 million of capital lease
obligations. Also, to finance a portion of the cash consideration for the Premcor Acquisition,
Valero entered into a $1.5 billion term bank loan, $700 million and $300 million of which was
repaid during September and October 2005, respectively.
During January 2005, Valero repurchased $40 million of its 7.375% notes due in March 2006 and $42
million of its 6.125% notes due in April 2007 at a premium of $4 million. In addition, during the
first nine months of 2005, Valero made scheduled debt repayments of $409 million related to various
notes as discussed in Note 7 of Condensed Notes to Consolidated Financial Statements. During
September 2005, Valero repurchased $190 million of the 7.75% senior subordinated notes assumed in
the Premcor Acquisition. In addition, in October 2005, Valero repurchased the 12.5% senior notes
assumed in the Premcor Acquisition for $182 million.
As of September 30, 2005, current portion of long-term debt and capital lease obligations
included mainly $266 million of notes which become due during the first quarter of 2006.
As of September 30, 2005, Valeros short-term and long-term purchase obligations increased by
approximately $27 billion from the amount reported as of December 31, 2004. The increase is
primarily attributable to purchase obligations arising from the Premcor Acquisition totaling
approximately $14 billion and an increase in obligations under crude oil supply contracts,
resulting from both new contracts entered into in the third quarter of 2005 and significantly
higher crude oil prices as of September 30, 2005.
None of Valeros contractual obligations have rating agency triggers that would automatically
require Valero to post additional collateral. However, in the event of certain downgrades of
Valeros senior unsecured debt to below investment grade ratings by Moodys Investors Service and
Standard & Poors Ratings Services, the cost of borrowings under some of Valeros bank credit
facilities and other arrangements would increase. Following the completion of the Premcor
Acquisition, Standard & Poors Ratings Services affirmed its rating of Valeros senior unsecured
debt of BBB minus and Moodys Investors Service confirmed
Valeros senior unsecured debt rating of Baa3
with a stable outlook.
48
Other Commercial Commitments
As of September 30, 2005, Valeros committed lines of credit included:
|
|
|
|
|
|
|
Borrowing
|
|
|
|
|
Capacity
|
|
Expiration
|
5-year revolving credit facility
|
|
$2.5 billion
|
|
August 2010
|
Canadian revolving credit facility
|
|
Cdn. $115 million
|
|
July 2006
|
In August 2005, Valero replaced its two $750 million revolving bank credit facilities with a $2.5
billion five-year revolving credit facility. The new revolving credit facility matures in August
2010. Borrowings under the new credit facility bear interest at LIBOR plus a margin, or an
alternate base rate as defined under the agreement. Valero will also be charged various fees and
expenses in connection with the facility, including facility fees and letter of credit fees. The
interest rate and fees under the revolving bank credit facility are subject to adjustment based
upon the credit ratings assigned to Valeros long-term debt. The facility includes certain
restrictive covenants including a coverage ratio and a debt-to-capitalization ratio.
As of September 30, 2005, Valero had $287 million of letters of credit outstanding under its
uncommitted short-term bank credit facilities, $514 million of letters of credit outstanding under
its committed facilities and Cdn. $8 million of letters of credit outstanding under its Canadian
facility.
As defined under Valeros revolving bank credit facilities, its debt-to-capitalization ratio (net
of cash) was 29.1% as of September 30, 2005 compared to 30.7% as of December 31, 2004.
Other
Through September 2005, Valero contributed cash of $60 million to its qualified pension plans,
representing its total expected contributions for 2005. No minimum contributions were required
under the Employee Retirement Income Security Act.
In connection with the Premcor Acquisition, Valero became the plan sponsor for three additional
pension plans and two additional other postretirement benefit plans. Prior to September 1, 2005,
Premcor had contributed $20 million to the former Premcor pension plans; Valero does not plan to
make further contributions to these plans in 2005.
Valero is subject to extensive federal, state and local environmental laws and regulations,
including those relating to the discharge of materials into the environment, waste management,
pollution prevention measures and characteristics and composition of gasolines and distillates.
Because environmental laws and regulations are becoming more complex and stringent and new
environmental laws and regulations are continuously being enacted or proposed, the level of future
expenditures required for environmental matters could increase in the future. In addition, any
major upgrades in any of Valeros refineries could require material additional expenditures to
comply with environmental laws and regulations. For additional information regarding Valeros
environmental matters, see Note 15 of Condensed Notes to Consolidated Financial Statements.
Valero believes it has sufficient funds from operations, and to the extent necessary, from the
public and private capital markets and bank markets, to fund its ongoing operating requirements.
Valero expects that, to the extent necessary, it can raise additional funds from time to time
through equity or debt financings. However, there can be no assurances regarding the availability
of any future financings or whether such financings can be made available on terms acceptable to
Valero.
49
As of June 30, 2005, Valero owned 45.5% of the outstanding units (including the 2% general partner
interest) of Valero L.P., a limited partnership that owns and operates crude oil and refined
product pipeline, terminalling and storage tank assets. On July 1, 2005, Valeros ownership
interest decreased to 23.4% as a result of the completion of the Kaneb Acquisition by Valero L.P.
Historically, Valero L.P. has issued common units to the public which have resulted in increases in
Valeros proportionate share of Valero L.P.s capital because the issuance price per unit exceeded
Valeros carrying amount per unit at the time of issuance. These increases in Valeros investment
in Valero L.P., however, have not been recognized by Valero in its consolidated financial
statements through September 30, 2005 and Valero is not permitted to do so until its subordinated
units convert to common units, which is expected to occur on April 1, 2006. See Note 6 of
Condensed Notes to Consolidated Financial Statements for a discussion of the amounts that will be
recognized, either in income or directly as a credit to equity, upon the conversion of the
subordinated units to common units. Subsequent to the conversion of the subordinated units, any
SAB 51 credits or charges generated upon the issuance of new units to the public by Valero L.P.
will be recognized immediately by Valero, either in income or directly in equity, depending on the
accounting policy adopted by Valero.
OFF-BALANCE SHEET ARRANGEMENTS
Accounts Receivable Sales Facility
As of December 31, 2004, Valero had an accounts receivable sales facility with a group of
third-party financial institutions to sell on a revolving basis up to $600 million of eligible
trade and credit card receivables, which was to mature in October 2005. In August 2005, Valero
amended this agreement to, among other things: (i) remove the credit card receivables from the
eligible pool of receivables, (ii) increase the size of the facility by $400 million to $1 billion,
and (iii) extend the maturity date to August 2008. As of September 30, 2005 and December 31, 2004,
the amount of eligible receivables sold to the third-party financial institutions was $1 billion
and $600 million, respectively.
CRITICAL ACCOUNTING POLICIES
The preparation of financial statements in accordance with United States generally accepted
accounting principles requires management to make estimates and assumptions that affect the amounts
reported in the consolidated financial statements and accompanying notes. Actual results could
differ from those estimates. Valeros critical accounting policies are disclosed in its Annual
Report on Form 10-K for the year ended December 31, 2004. No significant changes to Valeros
accounting policies have occurred subsequent to December 31, 2004.
50
Item 3. Quantitative and Qualitative Disclosures About Market Risk
COMMODITY PRICE RISK
The following tables provide information about Valeros derivative commodity instruments as of
September 30, 2005 and December 31, 2004 (dollars in millions, except for the weighted-average pay
and receive prices as described below), including:
|
|
|
fair value hedges held to hedge refining inventories and unrecognized firm commitments,
|
|
|
|
cash flow hedges held to hedge forecasted feedstock and product purchases, refined
product sales and natural gas purchases,
|
|
|
|
economic hedges held to:
|
|
|
|
manage price volatility in refinery feedstock and refined product inventories, and
|
|
|
|
manage price volatility in forecasted feedstock and product purchases, refined
product sales and natural gas purchases, and
|
|
|
|
trading activities held or issued for trading purposes.
|
Contract volumes are presented in thousands of barrels (for crude oil and refined products) or in
billions of British thermal units (for natural gas). The weighted-average pay and receive prices
represent amounts per barrel (for crude oil and refined products) or amounts per million British
thermal units (for natural gas). Volumes shown for swaps represent notional volumes, which are
used to calculate amounts due under the agreements. The gain (loss) on swaps is equal to the fair
value amount and represents the excess of the receive price over the pay price times the notional
contract volumes. For futures and options, the gain (loss) represents (i) the excess of the fair
value amount over the contract amount for long positions, or (ii) the excess of the contract amount
over the fair value amount for short positions. Additionally, for futures and options, the
weighted-average pay price represents the contract price for long positions and the
weighted-average receive price represents the contract price for short positions. The
weighted-average pay price and weighted-average receive price for options represents their strike
price.
As of September 30, 2005, Valero had approximately $182 million of unrealized after-tax losses on
certain cash flow hedge positions, primarily related to forward sales of distillates and associated
forward purchases of crude oil, which are reflected in accumulated other comprehensive income.
Valero expects that all of these cash flow hedges will be reclassified into income over the next 10
months as a result of hedged transactions that are forecasted to occur. The amount ultimately
realized in income, however, will differ as commodity prices change.
51
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2005
|
|
|
|
|
|
|
|
Wtd Avg
|
|
|
Wtd Avg
|
|
|
|
|
|
|
|
|
|
|
|
|
Contract
|
|
|
Pay
|
|
|
Receive
|
|
|
Contract
|
|
|
Fair
|
|
|
Gain
|
|
|
|
Volumes
|
|
|
Price
|
|
|
Price
|
|
|
Value
|
|
|
Value
|
|
|
(Loss)
|
|
Fair Value Hedges:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Futures long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
68,577
|
|
|
$
|
65.57
|
|
|
|
N/A
|
|
|
$
|
4,497
|
|
|
$
|
4,489
|
|
|
$
|
(8
|
)
|
Futures short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
82,540
|
|
|
|
N/A
|
|
|
$
|
65.83
|
|
|
|
5,433
|
|
|
|
5,449
|
|
|
|
(16
|
)
|
2006 (crude oil and refined products)
|
|
|
323
|
|
|
|
N/A
|
|
|
|
68.37
|
|
|
|
22
|
|
|
|
22
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash Flow Hedges:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Swaps long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
17,229
|
|
|
|
36.63
|
|
|
|
67.39
|
|
|
|
N/A
|
|
|
|
530
|
|
|
|
530
|
|
Swaps short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
17,229
|
|
|
|
89.41
|
|
|
|
41.45
|
|
|
|
N/A
|
|
|
|
(826
|
)
|
|
|
(826
|
)
|
Futures long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
5,106
|
|
|
|
77.11
|
|
|
|
N/A
|
|
|
|
394
|
|
|
|
440
|
|
|
|
46
|
|
2006 (crude oil and refined products)
|
|
|
687
|
|
|
|
79.47
|
|
|
|
N/A
|
|
|
|
55
|
|
|
|
61
|
|
|
|
6
|
|
Futures short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
3,338
|
|
|
|
N/A
|
|
|
|
72.74
|
|
|
|
243
|
|
|
|
281
|
|
|
|
(38
|
)
|
2006 (crude oil and refined products)
|
|
|
46
|
|
|
|
N/A
|
|
|
|
77.10
|
|
|
|
3
|
|
|
|
4
|
|
|
|
(1
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Economic Hedges:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Swaps long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
12,796
|
|
|
|
24.02
|
|
|
|
24.76
|
|
|
|
N/A
|
|
|
|
9
|
|
|
|
9
|
|
Swaps short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
9,008
|
|
|
|
38.39
|
|
|
|
37.49
|
|
|
|
N/A
|
|
|
|
(8
|
)
|
|
|
(8
|
)
|
Futures long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
36,638
|
|
|
|
74.48
|
|
|
|
N/A
|
|
|
|
2,729
|
|
|
|
2,757
|
|
|
|
28
|
|
2006 (crude oil and refined products)
|
|
|
163
|
|
|
|
73.56
|
|
|
|
N/A
|
|
|
|
12
|
|
|
|
14
|
|
|
|
2
|
|
Futures short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
41,389
|
|
|
|
N/A
|
|
|
|
71.67
|
|
|
|
2,966
|
|
|
|
3,004
|
|
|
|
(38
|
)
|
2005 (natural gas)
|
|
|
30
|
|
|
|
N/A
|
|
|
|
9.05
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2006 (crude oil and refined products)
|
|
|
100
|
|
|
|
N/A
|
|
|
|
65.16
|
|
|
|
6
|
|
|
|
8
|
|
|
|
(2
|
)
|
Options long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (natural gas)
|
|
|
1,070
|
|
|
|
7.87
|
|
|
|
N/A
|
|
|
|
(1
|
)
|
|
|
|
|
|
|
1
|
|
2006 (natural gas)
|
|
|
690
|
|
|
|
7.99
|
|
|
|
N/A
|
|
|
|
(1
|
)
|
|
|
|
|
|
|
1
|
|
Options short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
2,467
|
|
|
|
N/A
|
|
|
|
33.21
|
|
|
|
|
|
|
|
19
|
|
|
|
(19
|
)
|
2005 (natural gas)
|
|
|
710
|
|
|
|
N/A
|
|
|
|
7.79
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2006 (crude oil and refined products)
|
|
|
159
|
|
|
|
N/A
|
|
|
|
72.08
|
|
|
|
(1
|
)
|
|
|
(1
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Trading Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Swaps long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
8,080
|
|
|
|
30.43
|
|
|
|
57.01
|
|
|
|
N/A
|
|
|
|
215
|
|
|
|
215
|
|
2005 (natural gas)
|
|
|
1,178
|
|
|
|
10.87
|
|
|
|
14.21
|
|
|
|
N/A
|
|
|
|
4
|
|
|
|
4
|
|
2006 (crude oil and refined
products)
|
|
|
150
|
|
|
|
8.15
|
|
|
|
15.25
|
|
|
|
N/A
|
|
|
|
1
|
|
|
|
1
|
|
2006 (natural gas)
|
|
|
280
|
|
|
|
8.86
|
|
|
|
14.28
|
|
|
|
N/A
|
|
|
|
2
|
|
|
|
2
|
|
Swaps short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
7,780
|
|
|
|
59.21
|
|
|
|
30.57
|
|
|
|
N/A
|
|
|
|
(223
|
)
|
|
|
(223
|
)
|
2005 (natural gas)
|
|
|
1,178
|
|
|
|
14.21
|
|
|
|
10.81
|
|
|
|
N/A
|
|
|
|
(4
|
)
|
|
|
(4
|
)
|
2006 (crude oil and refined products)
|
|
|
1,350
|
|
|
|
17.43
|
|
|
|
13.17
|
|
|
|
N/A
|
|
|
|
(6
|
)
|
|
|
(6
|
)
|
2006 (natural gas)
|
|
|
280
|
|
|
|
14.28
|
|
|
|
8.68
|
|
|
|
N/A
|
|
|
|
(2
|
)
|
|
|
(2
|
)
|
52
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2005
|
|
|
|
|
|
|
|
Wtd Avg
|
|
|
Wtd Avg
|
|
|
|
|
|
|
|
|
|
|
|
|
Contract
|
|
|
Pay
|
|
|
Receive
|
|
|
Contract
|
|
|
Fair
|
|
|
Gain
|
|
|
|
Volumes
|
|
|
Price
|
|
|
Price
|
|
|
Value
|
|
|
Value
|
|
|
(Loss)
|
|
Trading Activities (continued):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Futures long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
13,461
|
|
|
$
|
62.76
|
|
|
|
N/A
|
|
|
$
|
845
|
|
|
$
|
918
|
|
|
$
|
73
|
|
2005 (natural gas)
|
|
|
7,360
|
|
|
|
9.14
|
|
|
|
N/A
|
|
|
|
67
|
|
|
|
105
|
|
|
|
38
|
|
2006 (crude oil and refined products)
|
|
|
593
|
|
|
|
63.14
|
|
|
|
N/A
|
|
|
|
37
|
|
|
|
41
|
|
|
|
4
|
|
2006 (natural gas)
|
|
|
840
|
|
|
|
8.03
|
|
|
|
N/A
|
|
|
|
7
|
|
|
|
10
|
|
|
|
3
|
|
Futures short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
11,809
|
|
|
|
N/A
|
|
|
$
|
62.03
|
|
|
|
732
|
|
|
|
802
|
|
|
|
(70
|
)
|
2005 (natural gas)
|
|
|
7,360
|
|
|
|
N/A
|
|
|
|
9.29
|
|
|
|
68
|
|
|
|
105
|
|
|
|
(37
|
)
|
2006 (crude oil and refined products)
|
|
|
1,243
|
|
|
|
N/A
|
|
|
|
63.76
|
|
|
|
79
|
|
|
|
84
|
|
|
|
(5
|
)
|
2006 (natural gas)
|
|
|
840
|
|
|
|
N/A
|
|
|
|
8.34
|
|
|
|
7
|
|
|
|
10
|
|
|
|
(3
|
)
|
Options long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
3,000
|
|
|
|
0.50
|
|
|
|
N/A
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (natural gas)
|
|
|
400
|
|
|
|
11.00
|
|
|
|
N/A
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Options short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
3,000
|
|
|
|
N/A
|
|
|
|
0.50
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (natural gas)
|
|
|
400
|
|
|
|
N/A
|
|
|
|
11.00
|
|
|
|
|
|
|
|
|
|
|
|
|
|
53
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2004
|
|
|
|
|
|
|
|
Wtd Avg
|
|
|
Wtd Avg
|
|
|
|
|
|
|
|
|
|
|
|
|
Contract
|
|
|
Pay
|
|
|
Receive
|
|
|
Contract
|
|
|
Fair
|
|
|
Gain
|
|
|
|
Volumes
|
|
|
Price
|
|
|
Price
|
|
|
Value
|
|
|
Value
|
|
|
(Loss)
|
|
Fair Value Hedges:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Futures long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
17,423
|
|
|
$
|
46.39
|
|
|
|
N/A
|
|
|
$
|
808
|
|
|
$
|
772
|
|
|
$
|
(36
|
)
|
Futures short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
26,726
|
|
|
|
N/A
|
|
|
$
|
46.00
|
|
|
|
1,229
|
|
|
|
1,190
|
|
|
|
39
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash Flow Hedges:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Swaps long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
67,378
|
|
|
|
37.05
|
|
|
|
42.84
|
|
|
|
N/A
|
|
|
|
390
|
|
|
|
390
|
|
Swaps short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
67,378
|
|
|
|
48.54
|
|
|
|
41.65
|
|
|
|
N/A
|
|
|
|
(464
|
)
|
|
|
(464
|
)
|
Futures long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
28,354
|
|
|
|
45.39
|
|
|
|
N/A
|
|
|
|
1,287
|
|
|
|
1,286
|
|
|
|
(1
|
)
|
Futures short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
23,152
|
|
|
|
N/A
|
|
|
|
45.95
|
|
|
|
1,064
|
|
|
|
1,067
|
|
|
|
(3
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Economic Hedges:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Swaps long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
3,505
|
|
|
|
11.49
|
|
|
|
11.37
|
|
|
|
N/A
|
|
|
|
|
|
|
|
|
|
Swaps short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
4,239
|
|
|
|
10.10
|
|
|
|
10.25
|
|
|
|
N/A
|
|
|
|
1
|
|
|
|
1
|
|
Futures long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
19,230
|
|
|
|
46.90
|
|
|
|
N/A
|
|
|
|
902
|
|
|
|
896
|
|
|
|
(6
|
)
|
Futures short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
17,787
|
|
|
|
N/A
|
|
|
|
47.55
|
|
|
|
846
|
|
|
|
824
|
|
|
|
22
|
|
Options long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
1,000
|
|
|
|
35.00
|
|
|
|
N/A
|
|
|
|
3
|
|
|
|
5
|
|
|
|
2
|
|
Options short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
4,201
|
|
|
|
N/A
|
|
|
|
21.69
|
|
|
|
(2
|
)
|
|
|
3
|
|
|
|
(5
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Trading Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Swaps long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
25,460
|
|
|
|
35.15
|
|
|
|
39.17
|
|
|
|
N/A
|
|
|
|
102
|
|
|
|
102
|
|
Swaps short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
23,585
|
|
|
|
42.66
|
|
|
|
38.20
|
|
|
|
N/A
|
|
|
|
(105
|
)
|
|
|
(105
|
)
|
Futures long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
15,956
|
|
|
|
45.09
|
|
|
|
N/A
|
|
|
|
719
|
|
|
|
725
|
|
|
|
6
|
|
2005 (natural gas)
|
|
|
210
|
|
|
|
7.04
|
|
|
|
N/A
|
|
|
|
1
|
|
|
|
1
|
|
|
|
|
|
Futures short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
21,781
|
|
|
|
N/A
|
|
|
|
45.81
|
|
|
|
998
|
|
|
|
1,003
|
|
|
|
(5
|
)
|
2005 (natural gas)
|
|
|
210
|
|
|
|
N/A
|
|
|
|
6.38
|
|
|
|
1
|
|
|
|
1
|
|
|
|
|
|
Options long:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
1,550
|
|
|
|
48.35
|
|
|
|
N/A
|
|
|
|
1
|
|
|
|
1
|
|
|
|
|
|
Options short:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 (crude oil and refined products)
|
|
|
150
|
|
|
|
N/A
|
|
|
|
10.55
|
|
|
|
|
|
|
|
|
|
|
|
|
|
54
INTEREST RATE RISK
The following table provides information about Valeros long-term debt and interest rate derivative
instruments (dollars in millions), all of which are sensitive to changes in interest rates. For
long-term debt, principal cash flows and related weighted-average interest rates by expected
maturity dates are presented. For interest rate swaps, the table presents notional amounts and
weighted-average interest rates by expected (contractual) maturity dates. Notional amounts are
used to calculate the contractual payments to be exchanged under the contract. Weighted-average
floating rates are based on implied forward rates in the yield curve at the reporting date.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2005
|
|
|
Expected Maturity Dates
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
There-
|
|
|
|
|
|
Fair
|
|
|
2005
|
|
2006
|
|
2007
|
|
2008
|
|
2009
|
|
after
|
|
Total
|
|
Value
|
Long-term Debt:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fixed rate
|
|
$
|
|
|
|
$
|
220
|
|
|
$
|
287
|
|
|
$
|
6
|
|
|
$
|
370
|
|
|
$
|
4,610
|
|
|
$
|
5,493
|
|
|
$
|
6,028
|
|
Average interest
rate
|
|
|
0.0
|
%
|
|
|
7.4
|
%
|
|
|
6.1
|
%
|
|
|
6.0
|
%
|
|
|
7.5
|
%
|
|
|
7.1
|
%
|
|
|
7.1
|
%
|
|
|
|
|
Floating rate
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
800
|
|
|
$
|
800
|
|
|
$
|
800
|
|
Average interest
rate
|
|
|
0.0
|
%
|
|
|
0.0
|
%
|
|
|
0.0
|
%
|
|
|
0.0
|
%
|
|
|
0.0
|
%
|
|
|
4.6
|
%
|
|
|
4.6
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest Rate Swaps
Fixed to Floating:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Notional amount
|
|
$
|
|
|
|
$
|
125
|
|
|
$
|
225
|
|
|
$
|
|
|
|
$
|
8
|
|
|
$
|
642
|
|
|
$
|
1,000
|
|
|
$
|
(22
|
)
|
Average pay rate
|
|
|
5.8
|
%
|
|
|
6.3
|
%
|
|
|
6.0
|
%
|
|
|
5.6
|
%
|
|
|
5.7
|
%
|
|
|
5.6
|
%
|
|
|
5.8
|
%
|
|
|
|
|
Average receive rate
|
|
|
6.0
|
%
|
|
|
6.0
|
%
|
|
|
5.8
|
%
|
|
|
5.7
|
%
|
|
|
5.7
|
%
|
|
|
5.6
|
%
|
|
|
5.7
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2004
|
|
|
Expected Maturity Dates
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
There-
|
|
|
|
|
|
Fair
|
|
|
2005
|
|
2006
|
|
2007
|
|
2008
|
|
2009
|
|
after
|
|
Total
|
|
Value
|
Long-term Debt:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fixed rate
|
|
$
|
410
|
|
|
$
|
260
|
|
|
$
|
329
|
|
|
$
|
6
|
|
|
$
|
208
|
|
|
$
|
3,164
|
|
|
$
|
4,377
|
|
|
$
|
4,790
|
|
Average interest
rate
|
|
|
8.1
|
%
|
|
|
7.4
|
%
|
|
|
6.1
|
%
|
|
|
6.0
|
%
|
|
|
3.6
|
%
|
|
|
6.8
|
%
|
|
|
6.8
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest Rate Swaps
Fixed to Floating:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Notional amount
|
|
$
|
|
|
|
$
|
125
|
|
|
$
|
225
|
|
|
$
|
|
|
|
$
|
8
|
|
|
$
|
642
|
|
|
$
|
1,000
|
|
|
$
|
(15
|
)
|
Average pay rate
|
|
|
5.0
|
%
|
|
|
5.6
|
%
|
|
|
5.6
|
%
|
|
|
5.4
|
%
|
|
|
5.8
|
%
|
|
|
6.2
|
%
|
|
|
5.9
|
%
|
|
|
|
|
Average receive rate
|
|
|
6.0
|
%
|
|
|
6.0
|
%
|
|
|
5.8
|
%
|
|
|
5.7
|
%
|
|
|
5.7
|
%
|
|
|
5.6
|
%
|
|
|
5.7
|
%
|
|
|
|
|
As of December 31, 2004, Valero had no long-term floating-rate debt.
FOREIGN CURRENCY RISK
As of September 30, 2005, Valero had commitments to purchase $318 million of U.S. dollars.
Valeros market risk was minimal on these contracts, as they matured on or before October 24, 2005.
55
Item 4. Controls and Procedures
(a) Evaluation of disclosure controls and procedures.
Valeros management has evaluated, with the participation of Valeros principal executive
and principal financial officers, the effectiveness of Valeros disclosure controls and
procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934) as of
the end of the period covered by this report, and has concluded that Valeros disclosure
controls and procedures were effective as of September 30, 2005 in ensuring that information
required to be disclosed by Valero in the reports that it files or submits under the
Exchange Act is recorded, processed, summarized and reported, within the time periods
specified in the Securities and Exchange Commissions rules and forms.
(b) Changes in internal control over financial reporting.
There has been no change in Valeros internal control over financial reporting (as defined
in Rule 13a-15(f) under the Exchange Act) that occurred during Valeros last fiscal quarter
that has materially affected, or is reasonably likely to materially affect, Valeros
internal control over financial reporting.
PART II OTHER INFORMATION
Item 1. Legal Proceedings.
Litigation
For the legal proceedings listed below, Valero hereby incorporates by reference into this Item the
disclosures made in Part I, Item 1 of this Report included in Note 15 of Condensed Notes to
Consolidated Financial Statements under the caption
Litigation.
|
|
|
Union Oil Company of California v. Valero Energy Corporation
|
|
|
|
|
Rosolowski v. Clark Refining & Marketing, Inc., et al.
|
Environmental Enforcement Matters
Texas Commission on Environmental Quality (TCEQ)
(Port Arthur Refinery). In September 2005, Valero
received two enforcement actions from the TCEQ relating to alleged Texas Clean Air Act violations
at the Port Arthur Refinery dating back to 2002. Combined, the TCEQ has assessed penalties
totaling $880,240 for these events. Valero has generally denied the allegations and has requested
hearings on the proposed orders.
56
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.
(a) Unregistered Sales of Equity Securities
. None.
(b) Use of Proceeds
. Not applicable.
(c) Issuer Purchases of Equity Securities
. The following table discloses purchases of shares
of Valeros common stock made by or on behalf of Valero during the quarterly period covered by this
report.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Number of
|
|
Maximum Number (or
|
|
|
|
|
|
|
|
|
|
|
Shares Purchased as
|
|
Approximate Dollar
|
|
|
|
|
|
|
|
|
|
|
Part of Publicly
|
|
Value) of Shares that May
|
|
|
Total Number of
|
|
Average Price
|
|
Announced Plans or
|
|
Yet Be Purchased Under
|
Period
|
|
Shares Purchased
|
|
Paid per Share
|
|
Programs
(1)
|
|
the Plans or Programs
|
July 2005
|
|
|
0
|
|
|
|
n/a
|
|
|
|
0
|
|
|
$361 million
|
August 2005
|
|
|
0
|
|
|
|
n/a
|
|
|
|
0
|
|
|
$361 million
|
September 2005
|
|
|
0
|
|
|
|
n/a
|
|
|
|
0
|
|
|
$361 million
|
Total
|
|
|
0
|
|
|
|
n/a
|
|
|
|
0
|
|
|
$361 million
|
|
|
|
(1)
|
|
Valeros existing stock repurchase program was publicly announced on December
3, 2001. The program authorizes Valero to purchase up to $400 million aggregate
purchase price of shares of Valeros common stock. The program has no expiration date.
|
Item 6. Exhibits.
|
|
|
Exhibit No.
|
|
Description
|
|
*2.01
|
|
Certificate of Merger of Premcor Inc. with and into Valero
Energy Corporation effective September 1, 2005.
|
|
|
|
*10.01
|
|
Restricted Unit Agreement dated as of October 20, 2005 between
Valero Energy Corporation and William E. Greehey.
|
|
|
|
*10.02
|
|
Form of Restricted Stock Agreement pursuant to the 2005
Omnibus Stock Incentive Plan.
|
|
|
|
*12.01
|
|
Statements of Computations of Ratios of Earnings to Fixed
Charges and Ratios of Earnings to Fixed Charges and Preferred
Stock Dividends.
|
|
|
|
*31.01
|
|
Rule 13a-14(a) Certifications (under Section 302 of the
Sarbanes-Oxley Act of 2002).
|
|
|
|
*32.01
|
|
Section 1350 Certifications (as adopted pursuant to Section
906 of the Sarbanes-Oxley Act of 2002).
|
57
SIGNATURE
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.
|
|
|
|
|
|
VALERO ENERGY CORPORATION
(Registrant)
|
|
|
By:
|
/s/ Michael S. Ciskowski
|
|
|
|
Michael S. Ciskowski
|
|
|
|
Executive Vice President and
Chief Financial Officer
(Duly Authorized Officer and Principal
Financial and Accounting Officer)
|
|
|
Date: November 9, 2005
58