UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED JUNE 30, 1998
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE TRANSITION PERIOD FROM . . . . . . . . TO . . . . . . . .
COMMISSION FILE NUMBER 1-3473
TESORO PETROLEUM CORPORATION
(Exact name of registrant as specified in its charter)
DELAWARE 95-0862768
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
8700 TESORO DRIVE, SAN ANTONIO, TEXAS 78217-6218
(Address of principal executive offices) (Zip Code)
210-828-8484
(Registrant's 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 X No
----- -----
There were 32,322,395 shares of the registrant's Common Stock outstanding at
July 31, 1998.
<PAGE>
TESORO PETROLEUM CORPORATION AND SUBSIDIARIES
QUARTERLY REPORT ON FORM 10-Q
FOR THE QUARTERLY PERIOD ENDED JUNE 30, 1998
TABLE OF CONTENTS
Page
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements (Unaudited)
Condensed Consolidated Balance Sheets - June 30, 1998 and
December 31, 1997. . . . . . . . . . . . . . . . . . . . . . 3
Condensed Statements of Consolidated Operations - Three Months
and Six Months Ended June 30, 1998 and 1997. . . . . . . . . 4
Condensed Statements of Consolidated Cash Flows - Six Months Ended
June 30, 1998 and 1997 . . . . . . . . . . . . . . . . . . . 5
Notes to Condensed Consolidated Financial Statements. . . . . 6
Item 2. Management's Discussion and Analysis of Financial
Condition and Results of Operations . . . . . . . . . . . . . 13
PART II. OTHER INFORMATION
Item 1. Legal Proceedings . . . . . . . . . . . . . . . . . . 26
Item 2. Changes in Securities and Use of Proceeds . . . . . . 27
Item 6. Exhibits and Reports on Form 8-K. . . . . . . . . . . 28
SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . . . 29
EXHIBIT INDEX. . . . . . . . . . . . . . . . . . . . . . . . . . 30
2
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<TABLE>
<CAPTION>
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
TESORO PETROLEUM CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(UNAUDITED)
(DOLLARS IN THOUSANDS EXCEPT PER SHARE AMOUNTS)
June 30, December 31,
1998 1997*
---- ----
ASSETS
<S> <C> <C>
CURRENT ASSETS
Cash and cash equivalents . . . . . . . . . . . . . . . . . . . $ 26,408 $ 8,352
Receivables, less allowance for doubtful accounts of $1,886
($1,373 at December 31, 1997). . . . . . . . . . . . . . . . . 112,053 76,282
Inventories:
Crude oil and wholesale refined products, at LIFO. . . . . . . 141,307 68,227
Merchandise and other refined products . . . . . . . . . . . . 18,748 13,377
Materials and supplies . . . . . . . . . . . . . . . . . . . . 15,391 5,755
Prepayments and other . . . . . . . . . . . . . . . . . . . . . 8,953 9,842
---------- ----------
Total Current Assets . . . . . . . . . . . . . . . . . . . . . 322,860 181,835
---------- ----------
PROPERTY, PLANT AND EQUIPMENT
Refining and marketing. . . . . . . . . . . . . . . . . . . . . 590,570 370,174
Exploration and production (full-cost method of accounting) . . 341,359 291,411
Marine services . . . . . . . . . . . . . . . . . . . . . . . . 49,851 43,072
Corporate . . . . . . . . . . . . . . . . . . . . . . . . . . . 16,138 13,689
---------- ----------
997,918 718,346
Less accumulated depreciation, depletion and amortization. . . 331,730 304,523
---------- ----------
Net Property, Plant and Equipment. . . . . . . . . . . . . . . 666,188 413,823
---------- ----------
OTHER ASSETS . . . . . . . . . . . . . . . . . . . . . . . . . . 52,840 32,150
---------- ----------
Total Assets. . . . . . . . . . . . . . . . . . . . . . . . . $1,041,888 $ 627,808
========== ==========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts payable. . . . . . . . . . . . . . . . . . . . . . . . $ 100,322 $ 58,767
Accrued liabilities and current income taxes payable. . . . . . 57,637 31,726
Current maturities of long-term debt and other obligations. . . 2,711 17,002
---------- ----------
Total Current Liabilities. . . . . . . . . . . . . . . . . . . 160,670 107,495
---------- ----------
DEFERRED INCOME TAXES. . . . . . . . . . . . . . . . . . . . . . 33,430 28,824
---------- ----------
OTHER LIABILITIES . . . . . . . . . . . . . . . . . . . . . . . 45,681 43,211
---------- ----------
LONG-TERM DEBT AND OTHER OBLIGATIONS, LESS
CURRENT MATURITIES . . . . . . . . . . . . . . . . . . . . . . 451,670 115,314
---------- ----------
COMMITMENTS AND CONTINGENCIES (Note E)
STOCKHOLDERS' EQUITY
Common stock, par value $0.16-2/3; authorized 50,000,000 shares;
26,885,080 shares issued (26,506,601 in 1997). . . . . . . . . 4,480 4,418
Additional paid-in capital. . . . . . . . . . . . . . . . . . . 198,319 190,925
Retained earnings . . . . . . . . . . . . . . . . . . . . . . . 153,275 140,980
Treasury stock, 323,162 common shares (216,453 in 1997), at cost (5,637) (3,359)
---------- ----------
Total Stockholders' Equity . . . . . . . . . . . . . . . . . . 350,437 332,964
---------- ----------
Total Liabilities and Stockholders' Equity. . . . . . . . . . $1,041,888 $ 627,808
========== ==========
<FN>
* The balance sheet at December 31, 1997 has been taken from the audited consolidated financial statements at that
date and condensed.
The accompanying notes are an integral part of these condensed consolidated financial statements.
</TABLE>
3
<PAGE>
<TABLE>
<CAPTION>
TESORO PETROLEUM CORPORATION AND SUBSIDIARIES
CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS
(UNAUDITED)
(IN THOUSANDS EXCEPT PER SHARE AMOUNTS)
Three Months Ended Six Months Ended
June 30, June 30,
--------------------- ---------------------
1998 1997 1998 1997
---- ---- ---- ----
<S> <C> <C> <C> <C>
REVENUES
Refining and marketing. . . . . . . . . . . . . . . . $ 207,506 $ 161,771 $ 347,719 $ 336,171
Exploration and production. . . . . . . . . . . . . . 21,534 18,590 43,756 41,948
Marine services . . . . . . . . . . . . . . . . . . . 29,157 30,338 61,975 65,833
Other income. . . . . . . . . . . . . . . . . . . . . 20,632 2,607 21,418 4,206
-------- -------- -------- --------
Total Revenues . . . . . . . . . . . . . . . . . . . 278,829 213,306 474,868 448,158
-------- -------- -------- --------
OPERATING COSTS AND EXPENSES
Refining and marketing. . . . . . . . . . . . . . . . 182,727 149,758 313,447 320,912
Exploration and production. . . . . . . . . . . . . . 3,490 2,937 7,415 5,782
Marine services . . . . . . . . . . . . . . . . . . . 26,874 29,499 57,471 63,715
Depreciation, depletion and amortization. . . . . . . 14,854 11,229 27,798 22,826
-------- -------- -------- --------
Total Segment Operating Costs and Expenses . . . . . 227,945 193,423 406,131 413,235
-------- -------- -------- --------
SEGMENT OPERATING PROFIT . . . . . . . . . . . . . . . 50,884 19,883 68,737 34,923
Other Operating Costs and Expenses . . . . . . . . . . (7,934) - (7,934) -
General and Administrative . . . . . . . . . . . . . . (3,852) (3,145) (7,224) (6,183)
Interest Expense, Net of Capitalized Interest in 1997 (5,753) (1,583) (8,418) (3,153)
Interest Income. . . . . . . . . . . . . . . . . . . . 305 890 413 1,324
Other Expense, Net . . . . . . . . . . . . . . . . . . (14,611) (941) (15,645) (2,232)
-------- -------- -------- --------
EARNINGS BEFORE INCOME TAXES AND
EXTRAORDINARY ITEM. . . . . . . . . . . . . . . . . . 19,039 15,104 29,929 24,679
Income Tax Provision . . . . . . . . . . . . . . . . . 8,162 5,466 12,993 8,910
-------- -------- -------- --------
EARNINGS BEFORE EXTRAORDINARY ITEM . . . . . . . . . . 10,877 9,638 16,936 15,769
Extraordinary Loss on Extinguishment of Debt, Net of
Income Tax Benefit of $2,401 in 1998. . . . . . . . . (4,641) - (4,641) -
-------- -------- -------- --------
NET EARNINGS . . . . . . . . . . . . . . . . . . . . . $ 6,236 $ 9,638 $ 12,295 $ 15,769
======== ======== ======== ========
NET EARNINGS PER SHARE - BASIC . . . . . . . . . . . . $ 0.23 $ 0.36 $ 0.47 $ 0.60
======== ======== ======== ========
NET EARNINGS PER SHARE - DILUTED . . . . . . . . . . . $ 0.23 $ 0.36 $ 0.46 $ 0.59
======== ======== ======== ========
WEIGHTED AVERAGE COMMON SHARES - BASIC . . . . . . . . 26,475 26,425 26,393 26,427
======== ======== ======== ========
WEIGHTED AVERAGE COMMON AND POTENTIALLY
DILUTIVE COMMON SHARES - DILUTED. . . . . . . . . . . 27,202 26,787 26,997 26,808
======== ======== ======== ========
The accompanying notes are an integral part of these condensed consolidated financial statements.
</TABLE>
4
<PAGE>
<TABLE>
<CAPTION>
TESORO PETROLEUM CORPORATION AND SUBSIDIARIES
CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS
(UNAUDITED)
(IN THOUSANDS)
Six Months Ended
June 30,
----------------------
1998 1997
---- ----
<S> <C> <C>
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES
Net earnings . . . . . . . . . . . . . . . . . . . . . . . . . $ 12,295 $ 15,769
Adjustments to reconcile net earnings to net cash from
operating activities:
Depreciation, depletion and amortization. . . . . . . . . . . 28,155 23,140
Loss on extinguishment of debt, net of income tax benefit . . 4,641 -
Amortization of deferred charges and other. . . . . . . . . . 712 333
Changes in operating assets and liabilities:
Receivables. . . . . . . . . . . . . . . . . . . . . . . . . 14,749 57,853
Inventories. . . . . . . . . . . . . . . . . . . . . . . . . (16,823) 811
Accounts payable and other current liabilities . . . . . . . (4,139) (46,362)
Obligation payments to State of Alaska . . . . . . . . . . . (3,008) (2,211)
Deferred income taxes. . . . . . . . . . . . . . . . . . . . 7,803 3,503
Other assets and liabilities . . . . . . . . . . . . . . . . (469) 4,514
--------- ---------
Net cash from operating activities. . . . . . . . . . . . . 43,916 57,350
--------- ---------
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES
Capital expenditures . . . . . . . . . . . . . . . . . . . . . (62,258) (44,799)
Acquisition and deposits (Note B). . . . . . . . . . . . . . . (252,517) -
Other. . . . . . . . . . . . . . . . . . . . . . . . . . . . . (851) (143)
--------- ---------
Net cash used in investing activities . . . . . . . . . . . (315,626) (44,942)
--------- ---------
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Borrowings under revolving credit facilities and term loans,
net of repayments . . . . . . . . . . . . . . . . . . . . . . 393,000 2,182
Refinancing of debt and obligations. . . . . . . . . . . . . . (89,940) -
Financing costs and expenses . . . . . . . . . . . . . . . . . (10,135) -
Payments of other long-term debt . . . . . . . . . . . . . . . (1,986) (2,293)
Other. . . . . . . . . . . . . . . . . . . . . . . . . . . . . (1,173) (237)
--------- ---------
Net cash from (used in) financing activities. . . . . . . . 289,766 (348)
--------- ---------
INCREASE IN CASH AND CASH EQUIVALENTS. . . . . . . . . . . . . . 18,056 12,060
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD . . . . . . . . . 8,352 22,796
--------- ---------
CASH AND CASH EQUIVALENTS, END OF PERIOD . . . . . . . . . . . . $ 26,408 $ 34,856
========= =========
SUPPLEMENTAL CASH FLOW DISCLOSURES
Interest paid, net of $114 capitalized in 1997 . . . . . . . . $ 3,592 $ 1,326
========= =========
Income taxes paid. . . . . . . . . . . . . . . . . . . . . . . $ 5,965 $ 18,872
========= =========
The accompanying notes are an integral part of these condensed consolidated financial statements.
</TABLE>
5
<PAGE>
TESORO PETROLEUM CORPORATION AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
<PAGE>
NOTE A - BASIS OF PRESENTATION
The interim condensed consolidated financial statements and notes thereto of
Tesoro Petroleum Corporation and its subsidiaries (collectively, the "Company"
or "Tesoro") have been prepared by management without audit pursuant to the
rules and regulations of the Securities and Exchange Commission ("SEC").
Accordingly, the accompanying financial statements reflect all adjustments that,
in the opinion of management, are necessary for a fair presentation of results
for the periods presented. Such adjustments are of a normal recurring nature.
Certain information and notes normally included in financial statements prepared
in accordance with generally accepted accounting principles have been condensed
or omitted pursuant to the SEC's rules and regulations. However, management
believes that the disclosures presented herein are adequate to make the
information not misleading. The accompanying condensed consolidated financial
statements and notes should be read in conjunction with the consolidated
financial statements and notes thereto contained in the Company's Annual Report
on Form 10-K for the year ended December 31, 1997.
The preparation of these condensed consolidated financial statements required
the use of management's best estimates and judgment that affect the reported
amounts of assets and liabilities and disclosures of contingent assets and
liabilities at the date of the financial statements and the reported amounts of
revenues and expenses during the periods. Actual results could differ from
those estimates. The results of operations for any interim period are not
necessarily indicative of results for the full year.
Earnings per share have been restated for prior periods to conform with the
requirements of Statement of Financial Accounting Standard ("SFAS") No. 128
which establishes standards for computing and presenting basic and diluted
earnings per share calculations.
NOTE B - ACQUISITIONS
Hawaii Refinery Acquisition
On May 29, 1998, the Company completed the acquisition (the "Hawaii
Acquisition") of all of the outstanding capital stock of BHP Petroleum Americas
Refining Inc. and BHP Petroleum South Pacific Inc. (together, "BHP Hawaii"),
both of which were affiliates of The Broken Hill Proprietary Company Limited
("BHP"). The Hawaii Acquisition included a 95,000-barrel per day refinery (the
"Hawaii Refinery") and 32 retail gasoline stations located in Hawaii. In
addition, Tesoro and a BHP affiliate entered into a two-year crude supply
agreement pursuant to which the BHP affiliate will assist Tesoro in acquiring
crude oil feedstock sourced outside of North America and arrange for the
transportation of such crude oil to the Hawaii Refinery.
Tesoro paid $243.5 million in cash for the Hawaii Acquisition, including $68.5
million for estimated net working capital. The cash purchase price is subject
to post-closing adjustments. In addition, Tesoro issued an unsecured,
non-interest bearing, promissory note ("BHP Note") for the purchase in the
amount of $50 million, payable in five equal annual installments of $10 million
each, beginning in 2009. The BHP Note provides for early payment to the extent
of one-half of the amount by which earnings from the acquired assets, before
interest expense, income taxes and depreciation, depletion and amortization, as
specified in the BHP Note, exceed $50 million in any calendar year.
The Hawaii Acquisition was accounted for as a purchase in the second quarter of
1998 whereby the purchase price was allocated to the assets acquired and
liabilities assumed based upon their respective fair market values at the date
of acquisition. The accompanying financial statements reflect the preliminary
allocation of the purchase price, as the purchase price allocation has not been
finalized. The Company is awaiting certain financial information regarding
assets acquired and liabilities assumed, including final appraisals on property
acquired and valuations on certain assumed liabilities. Included in the
preliminary allocation was an estimated $14.6 million present value of the BHP
Note. The effects of accelerated payments under the BHP Note, if required,
would be accounted for as additional costs of the acquired assets and amortized
over the remaining life of the assets.
Under purchase accounting, BHP Hawaii's results have been included in Tesoro's
consolidated financial statements since the date of acquisition. Had BHP
Hawaii's results been included in Tesoro's results since January 1, 1997, and
the Refinancing and Offerings completed (as defined in Note C below), Tesoro's
consolidated results for the six months ended June 30, 1998 on a pro forma basis
would have reflected revenues of approximately $800 million,
6
<PAGE>
earnings before extraordinary item of $19 million ($0.42 per basic and $0.41 per
diluted share after preferred dividends) and net earnings of $15 million ($0.27
per basic and diluted share after preferred dividends). Tesoro's consolidated
results for the six months ended June 30, 1997, on a pro forma basis would have
reflected revenues of approximately $900 million and net earnings of $13 million
($0.21 per basic and diluted share after preferred dividends).
Washington State Refinery Acquisition
On August 10, 1998, the Company completed the acquisition (the "Washington
Acquisition" and together with the Hawaii Acquisition, the "Acquisitions"),
effective August 1, 1998, of all of the outstanding stock of Shell Anacortes
Refining Company ("Shell Washington"), an affiliate of Shell Oil Company
("Shell"). The Washington Acquisition included an 108,000-barrel per day
refinery (the "Washington Refinery") in Anacortes, Washington and related
assets. The total cash purchase price for the Washington Acquisition was $237
million plus $39.6 million for estimated working capital, which is subject to
post-closing adjustments. The Washington Acquisition will be accounted for as a
purchase in the third quarter of 1998.
Exploration and Production
Through the first half of 1998, the Exploration and Production segment acquired
an interest in 46,900 gross acres (21,200 net) for $3.4 million, located
primarily in Chambers and Jefferson Counties in the Frio/Vicksburg Trend and in
Wheeler County in the Texas Panhandle.
In addition, in August 1998 the Company purchased a 50% working interest in the
Stiles Ranch Field which includes 10,200 gross acres located in Wheeler County
which are adjacent to 8,000 gross acres acquired earlier in the year. The
interests acquired were producing approximately 2.6 million cubic feet
equivalent per day, net, as of June 1, 1998 from 25 wells in the Granite Wash
formation. The acquisition price included $8 million cash plus the conveyance
of a 25% working interest in an undeveloped prospect owned by the Company in
South Texas.
NOTE C - LONG-TERM DEBT AND EQUITY
Interim Credit Facility and Senior Credit Facility
In conjunction with closing the Hawaii Acquisition (see Note B), on May 29,
1998, Tesoro refinanced substantially all of its then-existing indebtedness (the
"Refinancing"). The Company recorded an extraordinary loss on early
extinguishment of debt of approximately $7.0 million pretax ($4.6 million
aftertax, or $0.17 per basic and diluted share) for the Refinancing during the
second quarter of 1998.
The total amount of funds required by Tesoro to complete the Hawaii Acquisition
and the Refinancing, to pay related fees and expenses and for general corporate
purposes was approximately $432 million, which was financed through a secured
credit facility (the "Interim Credit Facility") provided by Lehman Commercial
Paper Inc. ("LCPI"), an affiliate of Lehman Brothers Inc. The Interim Credit
Facility replaced the Company's previous corporate revolving credit agreement.
Subsequent to June 30, 1998, the Company refinanced all borrowings under the
Interim Credit Facility with net proceeds from the Offerings (as defined below)
and borrowings under the Senior Credit Facility (as defined below).
On July 2, 1998, and in connection with the Notes Offering (defined below) and
the Washington Acquisition, the Company entered into a senior credit facility
(the "Senior Credit Facility") with a group of lenders led by LCPI in the amount
of $500 million. The Senior Credit Facility is comprised of term loan
facilities aggregating $200 million (two $100 million tranches, the "Tranche A
Term Loans" and the "Tranche B Term Loan") and a $300 million revolving credit
facility (the "Revolver"). In addition, the Company may borrow up to $50
million under the Tranche A Term Loans, in up to five draws, for a period of up
to six months following July 2, 1998. The Senior Credit Facility is guaranteed
by substantially all of the Company's active direct and indirect subsidiaries
(the "Guarantors") and is secured by substantially all of the domestic assets of
the Company and each of the Guarantors. The Senior Credit Facility requires the
Company to maintain specified levels of consolidated leverage and interest
coverage and contains other covenants and restrictions customary in credit
arrangements of this kind (see Changes in Securities and Use of Proceeds in Part
II, Item 2, contained herein).
7
<PAGE>
The Revolver and the Tranche A Term Loans bear interest, at the Company's
election, at either the Base Rate (as defined in the Senior Credit Facility)
plus a margin ranging from 0.00% to 0.625% or the Eurodollar Rate (as defined in
the Senior Credit Facility) plus a margin ranging from 1.125% to 2.125%. The
Tranche B Term Loan bears interest, at the Company's election, at either the
Base Rate plus a margin ranging from 0.50% to 0.625% or the Eurodollar Rate plus
a margin ranging from 2.00% to 2.125%. Provisions of the Senior Credit Facility
require prepayments to the Tranche A Term Loans and Tranche B Term Loan, with
customary exceptions, in an amount equal to 100% of the net proceeds of certain
incurred indebtedness, 100% of the net proceeds received by the Company and its
subsidiaries (other than certain net proceeds reinvested in the business of the
Company or its subsidiaries) from the disposition of any assets, including
proceeds from the sale of stock of any of the Company's subsidiaries and a
percentage of excess cash flow, depending on certain credit statistics.
In addition to funding the cash consideration of the Acquisitions and
Refinancing, the Senior Credit Facility provides the Company with enhanced
financial flexibility, such as increased working capital capacity and funds for
general corporate purposes.
Equity Offerings
On May 4, 1998, the Company filed a universal shelf registration statement
("Universal Shelf Registration Statement") with the SEC for $600 million of debt
or equity securities for acquisitions or general corporate purposes. The
Universal Shelf Registration Statement was declared effective by the SEC on May
14, 1998. The Company offered Premium Income Equity Securities ("PIES") and
Common Stock (collectively, the "Equity Offerings") from the Universal Shelf
Registration Statement to provide partial funding for the Acquisitions discussed
in Note B. On July 1, 1998, the Company issued 9,000,000 PIES, representing
fractional interests in the Company's 7.25% Mandatorily Convertible Preferred
Stock, with gross proceeds of approximately $143.4 million, and 5,000,000 shares
of Common Stock, with gross proceeds of $79.7 million. Upon exercise of the
over-allotment options granted to the underwriters of the Equity Offerings, on
July 8, 1998, the Company issued 1,350,000 PIES with gross proceeds of $21.5
million and 750,000 shares of Common Stock with gross proceeds of $11.9 million.
Holders of PIES are entitled to receive a cash dividend. The PIES will
automatically convert into shares of Common Stock on July 1, 2001, at a rate
based upon a formula dependent upon the market price of Common Stock. Before
July 1, 2001, each PIES is convertible, at the option of the holder thereof,
into 0.8455 shares of Common Stock, subject to adjustment in certain events.
For further information on PIES, see Part II, Item 2, Changes in Securities and
Use of Proceeds.
Notes Offering
On July 2, 1998, concurrently with the syndication of the Senior Credit
Facility, the Company issued $300 million aggregate principal amount of 9%
Senior Subordinated Notes ("Senior Subordinated Notes") due 2008 (the "Notes
Offering", and together with the Equity Offerings, the "Offerings") through a
private offering eligible for Rule 144A. The Senior Subordinated Notes have a
ten-year maturity without sinking fund requirements and are subject to optional
redemption by the Company after five years at declining premiums. The indenture
(the "Indenture") for the Senior Subordinated Notes contains covenants and
restrictions which are customary for notes of this nature. The restrictions
under the Indenture are less restrictive than those in the Senior Credit
Facility (see Part II, Item 2). On August 7, 1998, a Registration Statement was
declared effective by the SEC whereby the Company is offering, upon the terms
and subject to the conditions set forth in the related Prospectus, to exchange
$1,000 principal amount of its registered 9% Senior Subordinated Notes due 2008,
Series B (the "Exchange Notes"), for each $1,000 principal amount of its
unregistered and outstanding Senior Subordinated Notes due 2008. The terms of
the Exchange Notes are identical in all material respects to the terms of the
Senior Subordinated Notes, except as described in the Prospectus.
Borrowings under the Senior Credit Facility, together with the net proceeds from
the Offerings, were used to fund the cash purchase price of the Washington
Acquisition, to refinance the Interim Credit Facility (a portion of which was
used to finance the Hawaii Acquisition), to pay certain fees and expenses
related to these transactions and for general corporate purposes (including
working capital requirements and capital expenditures).
8
<PAGE>
Capitalization
The following table sets forth the consolidated capitalization of the Company as
of June 30, 1998 on an (i) historical basis and (ii) as adjusted to give effect
to the Acquisitions, the Offerings including the exercise of the over-allotment
options and the initial borrowings under the Senior Credit Facility
(collectively, the "Transactions") (in millions):
<TABLE>
<CAPTION>
June 30, 1998
-----------------------
As Adjusted
Tesoro for the
Historical Transactions
---------- ------------
<S> <C> <C>
Total Debt and Other Obligations, Including Current Maturities:
Interim Credit Facility . . . . . . . . . . . . . . . . . . . $ 421.0 $ -
Senior Credit Facility. . . . . . . . . . . . . . . . . . . . - 152.0
Senior Subordinated Notes . . . . . . . . . . . . . . . . . . - 298.3
BHP Note (see Note B) . . . . . . . . . . . . . . . . . . . . 14.7 14.7
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18.7 18.7
------ ------
Total Debt and Obligations . . . . . . . . . . . . . . . . . 454.4 483.7
Mandatorily Convertible Preferred Stock. . . . . . . . . . . . - 164.9
Common Stockholders' Equity. . . . . . . . . . . . . . . . . . 350.4 431.9
------ ------
Total Capitalization . . . . . . . . . . . . . . . . . . . . $ 804.8 $ 1,080.5
====== ======
</TABLE>
The Company's debt-to-capitalization ratio at June 30, 1998 was approximately
56% on an historical basis and 45% on a pro forma basis.
Other
In connection with filing the Universal Shelf Registration Statement in May
1998, the Company's Board of Directors approved terminating the repurchase of
Tesoro's Common Stock under a repurchase program that was initiated in May 1997.
At the 1998 Annual Meeting of Stockholders held on July 29, 1998, the Company's
shareholders approved, among other proposals, to (i) amend the Company's
Restated Certificate of Incorporation to increase the number of authorized
shares of the Company's Common Stock from 50,000,000 to 100,000,000 and (ii)
increase the number of shares which can be granted under the Company's Amended
and Restated Executive Long-Term Incentive Plan from 2,650,000 to 4,250,000.
9
<PAGE>
NOTE D - BUSINESS SEGMENTS
The Company has adopted SFAS No. 131 which establishes standards for reporting
information about operating segments in annual financial statements and requires
that selected information be included in interim financial reports. Segment
operating profit includes those revenues and expenses that are directly
attributable to management of the respective segment. For the periods presented
below, revenues were generated from sales to external customers and there were
no intersegment revenues. Segment information for the three months and six
months ended June 30, 1998 and 1997 is as follows (in millions):
<TABLE>
<CAPTION>
Three Months Ended Six Months Ended
June 30, June 30,
------------------ ------------------
1998 1997 1998 1997
---- ---- ---- ----
<S> <C> <C> <C> <C>
Refining and Marketing:
Operating revenues. . . . . . . . . . . . . . . . . . . . . . . . . $ 207.6 $ 161.8 $ 347.8 $ 336.2
Other income (expense). . . . . . . . . . . . . . . . . . . . . . . (0.5) - (0.5) -
Operating costs and expenses. . . . . . . . . . . . . . . . . . . . 182.8 149.8 313.5 321.0
Depreciation, depletion and amortization. . . . . . . . . . . . . . 4.3 3.2 7.3 6.3
------- ------- ------- -------
Total Refining and Marketing Segment Operating Profit. . . . . . . 20.0 8.8 26.5 8.9
------- ------- ------- -------
Exploration and Production:
Operating revenues. . . . . . . . . . . . . . . . . . . . . . . . . 21.6 18.6 43.8 42.0
Other income. . . . . . . . . . . . . . . . . . . . . . . . . . . . 21.2 2.5 21.8 4.1
Operating costs and expenses. . . . . . . . . . . . . . . . . . . . 3.6 2.9 7.4 5.8
Depreciation, depletion and amortization. . . . . . . . . . . . . . 10.0 7.6 19.4 15.7
------- ------- ------- -------
Total Exploration and Production Segment Operating
Profit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29.2 10.6 38.8 24.6
------- ------- ------- -------
Marine Services:
Operating revenues. . . . . . . . . . . . . . . . . . . . . . . . . 29.1 30.3 61.9 65.8
Operating costs and expenses. . . . . . . . . . . . . . . . . . . . 27.0 29.4 57.4 63.6
Depreciation, depletion and amortization. . . . . . . . . . . . . . 0.5 0.4 1.1 0.8
------- ------- ------- -------
Total Marine Services Segment Operating Profit . . . . . . . . . . 1.6 0.5 3.4 1.4
------- ------- ------- -------
Segment Operating Profit . . . . . . . . . . . . . . . . . . . . . . $ 50.8 $ 19.9 $ 68.7 $ 34.9
======= ======= ======= =======
</TABLE>
<TABLE>
<CAPTION>
Total assets for each operating segment are as follows (in millions):
June 30, December 31,
1998 1997
-------- ------------
<S> <C> <C>
Refining and Marketing . . . . . . . . . . . . . . . . . . . . . . . $ 686.7 $ 337.4
Exploration and Production . . . . . . . . . . . . . . . . . . . . . 234.4 209.0
Marine Services. . . . . . . . . . . . . . . . . . . . . . . . . . . 61.1 59.3
----- -----
Total Segment Assets. . . . . . . . . . . . . . . . . . . . . . . . $ 982.2 $ 605.7
===== =====
</TABLE>
NOTE E - COMMITMENTS AND CONTINGENCIES
Environmental
The Company is subject to extensive federal, state and local environmental laws
and regulations. These laws, which change frequently, regulate the discharge of
materials into the environment and may require the Company to remove or mitigate
the environmental effects of the disposal or release of petroleum or chemical
substances at various sites or install additional controls or other
modifications or changes in use for certain emission sources. The Company is
currently involved with a waste disposal site near Abbeville, Louisiana, at
which it has been named a potentially responsible party ("PRP") under the
Federal Superfund law. Although this law might impose joint and several
liability upon each party at the site, the extent of the Company's allocated
financial contributions to the cleanup of the site is expected to be limited
based upon the number of companies, volumes of waste involved and an estimated
total cost of approximately $500,000 among all of the parties to close the site.
The Company is currently involved
10
<PAGE>
in settlement discussions with the Environmental Protection Agency ("EPA") and
other PRPs at the Abbeville, Louisiana site. The Company expects, based on
these discussions, that its liability will not exceed $25,000. The Company is
also involved in remedial responses and has incurred cleanup expenditures
associated with environmental matters at a number of sites, including certain of
its current and prior-owned properties. For further information regarding
environmental matters, see Legal Proceedings in Part II, Item 1, included
herein.
At June 30, 1998, the Company's accruals for environmental expenses totaled
$10.9 million, which includes approximately $2.5 million for remediation of the
Kenai Pipe Line ("KPL") properties (funded by the former owners of KPL through a
restricted escrow deposit). Based on currently available information, including
the participation of other parties or former owners in remediation actions, the
Company believes these accruals to be adequate.
In connection with the Hawaii Acquisition discussed in Note B, certain
subsidiaries of BHP (the "BHP Sellers") and the Company have executed a separate
environmental agreement, whereby the BHP Sellers have indemnified the Company
for environmental costs arising out of conditions which existed at or prior to
closing. This indemnification is subject to a maximum limit of $9.5 million and
expires after a period of ten years. Under the environmental agreement, the
first $5.0 million of these liabilities will be the responsibility of the BHP
Sellers and the next $6.0 million will be shared on the basis of 75% by the BHP
Sellers and 25% by the Company. Certain environmental claims arising out of
prior operations will not be subject to the $9.5 million limit or the ten-year
time limit.
Under the agreement related to the Washington Acquisition discussed in Note B,
Shell Refining Holding Company, a subsidiary of Shell (the "Shell Seller"),
generally has agreed to indemnify the Company for environmental liabilities at
the Washington Refinery arising out of conditions which existed at or prior to
the closing date and identified by the Company prior to August 1, 2001. The
Company is responsible for environmental costs up to the first $0.5 million each
year, after which the Shell Seller will be responsible for annual environmental
costs up to $1.0 million. Annual costs greater than $1.0 million will be shared
on a 50%/50% basis between the Company and the Shell Seller, subject to an
aggregate maximum of $5.0 million and a ten-year term. Conditions that may
require additional expenditures may exist for the Washington Acquisition,
including but not limited to expenditures for compliance with the Clean Air Act.
The amount of such future expenditures cannot currently be determined by the
Company.
In addition to environmental expenses, the Company anticipates that it will make
capital improvements of approximately $10 million in 1998 and $5 million in 1999
to comply with environmental laws and regulations affecting its Alaska, Hawaii
and the Gulf Coast operations. In addition, capital expenditures for
alternative secondary containment systems for existing storage tank facilities
in Alaska are estimated to be $2 million in 1998 and $2 million in 1999, with a
remaining $5 million to be spent by 2002.
Conditions that require additional expenditures may exist for various Company
sites, including, but not limited to, the Company's refineries, retail stations
(current and closed locations) and petroleum product terminals, and for
compliance with the Clean Air Act. The amount of such future expenditures cannot
currently be determined by the Company.
Other
The Company's results for the second quarter of 1998 reflected receipt of
approximately $21 million pretax ($14 million aftertax) from an operator in the
Bob West Field, representing funds that are no longer needed as a contingency
reserve for litigation.
NOTE F - INCENTIVE COMPENSATION STRATEGY
In June 1996, the Company's Board of Directors unanimously approved a special
incentive compensation strategy in order to encourage a longer-term focus for
all employees to perform at an outstanding level. The strategy provided
eligible employees with incentives to achieve a significant increase in the
market price of the Company's Common Stock. Under the strategy, awards would be
earned only if the market price of the Company's Common Stock reached an average
price per share of $20 or higher over any 20 consecutive trading days after June
30, 1997 and before December 31, 1998 (the "Performance Target"). In connection
with this strategy, non-executive employees would be able to earn cash bonuses
equal to 25% of their individual payroll amounts for the previous twelve
complete
11
<PAGE>
months and certain executives were granted, from the Company's Amended and
Restated Executive Long-Term Incentive Plan ("Plan"), a total of 340,000 stock
options at an exercise price of $11.375 per share, the fair market value (as
defined in the Plan) of a share of the Company's Common Stock on the date of
grant, and 350,000 shares of restricted Common Stock, all of which vest only
upon achieving the Performance Target.
On May 12, 1998, the Performance Target was achieved which resulted in a pretax
charge of approximately $20 million ($10 million related to the vesting of
restricted stock awards and stock options and $10 million in cash) in the second
quarter of 1998. The pretax charge included approximately $8 million in other
operating costs and expenses and approximately $12 million in other expense. On
an aftertax basis, the charge was approximately $13 million, representing
approximately 5% of the total aggregate increase in shareholder value since
approval of the special incentive strategy in 1996.
12
<PAGE>
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
Those statements in the Management's Discussion and Analysis that are not
historical in nature should be deemed forward-looking statements that are
inherently uncertain. See "Forward-Looking Statements" on page 24 for
discussion of the factors which could cause actual results to differ materially
from those projected in such statements.
GENERAL
The Company's strategy is to (i) maximize return on capital employed and
increase the competitiveness of each of its business units by reducing costs,
increasing operating efficiencies and optimizing existing assets and (ii) expand
its overall market presence through a combination of internal growth initiatives
and selective acquisitions which are both accretive to earnings and provide
significant operational synergies. In 1998, the Company plans to further
improve profitability in the Refining and Marketing segment by enhancing
processing capabilities, strengthening marketing channels and improving supply
and transportation functions. In the Exploration and Production segment, the
strategy includes evaluating ways in which the Company can continue to diversify
its oil and gas reserve base through both acquisitions and the drill bit and
enhanced technical capabilities. The Company has made significant progress in
diversifying its U.S. operations to areas other than the Bob West Field and has
taken steps to begin serving emerging markets in South America. Improved
profitability has positioned the Marine Services segment to participate in the
consolidation of the industry by pursuing opportunities for expansion, as well
as optimizing existing operations.
Tesoro acquired the Hawaiian refining and marketing assets of two subsidiaries
of BHP in May 1998 and acquired the Washington Refinery and related refining
assets from a subsidiary of Shell in August 1998. The Acquisitions are expected
to triple Tesoro's annual revenues and significantly increase the scope of
Tesoro's refining and marketing operations. Tesoro expects that the results of
the Acquisitions will be accretive to earnings and cash flows beginning in 1999.
The impact of the Acquisitions on earnings and cash flows may be neutral in 1998
primarily due to the mid-year timing of the Acquisitions and a scheduled
maintenance turnaround at the Hawaii Refinery in the summer of 1998. The
Company believes that there are significant cost saving and revenue enhancement
opportunities available by integrating the Hawaii Refinery and Washington
Refinery with its Alaskan operations and has currently identified $25 million of
potential annual cost saving and revenue enhancing synergies. Management
expects to begin to realize such synergies in the fourth quarter of 1998 with
the full annual impact to be achieved in the fiscal year ending December 31,
1999. The Company will continue to pursue other opportunities that are
operationally and geographically complementary with its asset base.
As part of the Company's long-term strategy, growth initiatives are planned in
1998 with capital spending projected to total $222 million, which includes
estimated capital expenditures for the operations recently acquired. This
capital spending projection represents an increase of 50% over 1997 capital
expenditures. Approximately 62% of the 1998 projected capital spending is
directed toward increased drilling and other related exploration costs, both in
Bolivia and the U.S. Another 33% is planned for downstream operations, primarily
improvements for retail marketing and refining operations. The remaining 5% of
the projected capital spending is dedicated to corporate expenditures, primarily
upgrading information systems.
The Company operates in an environment where its results and cash flows are
sensitive to volatile changes in energy prices. Major shifts in the cost of
crude oil used for refinery feedstocks and the price of refined products can
result in a change in margin from the Refining and Marketing operations, as
prices received for refined products may or may not keep pace with changes in
crude oil costs. These energy prices, together with volume levels, also
determine the carrying value of crude oil and refined product inventory. The
Company uses the last-in, first-out ("LIFO") method of accounting for
inventories of crude oil and U.S. wholesale refined products in its Refining and
Marketing segment. This method results in inventory carrying amounts that are
less likely to represent current values and in costs of sales which more closely
represent current costs. Similarly, changes in natural gas, condensate and oil
prices impact revenues and the present value of estimated future net revenues
and cash flows from the Company's Exploration and Production operations. The
Company may increase or decrease its natural gas production in response to
market conditions. The carrying value of oil and gas assets may be subject to
noncash write-downs based on changes in natural gas prices and other determining
factors. Changes in natural gas prices also influence the level of drilling
activity in the Gulf of Mexico. The Company's Marine Services operation, whose
customers include offshore drilling contractors and related industries, could be
impacted by significant fluctuations in natural gas prices. The Company's
Marine Services segment uses the first-in, first-out ("FIFO") method of
accounting for inventories of fuels. Changes in fuel prices can significantly
impact inventory valuations and costs of sales in this segment.
13
<PAGE>
RESULTS OF OPERATIONS - THREE MONTHS AND SIX MONTHS ENDED JUNE 30, 1998 COMPARED
WITH THREE MONTHS AND SIX MONTHS ENDED JUNE 30, 1997
SUMMARY
Tesoro's net earnings of $6.2 million, or $0.23 per share, for the three months
ended June 30, 1998 ("1998 Quarter") compare with net earnings of $9.7 million,
or $0.36 per share, for the three months ended June 30, 1997 ("1997 Quarter").
For the year-to-date period, net earnings of $12.3 million, or $0.47 per basic
share ($0.46 per diluted share), for the six months ended June 30, 1998 ("1998
Period") compare with net earnings of $15.8 million, or $0.60 per basic share
($0.59 per diluted share), for the six months ended June 30, 1997 ("1997
Period"). Significant items which affect the comparability between results for
1998 and 1997 are highlighted in the table below (in millions except per share
amounts):
<TABLE>
<CAPTION>
Three Months Ended Six Months Ended
June 30, June 30,
------------------ ----------------
1998 1997 1998 1997
---- ---- ---- ----
<S> <C> <C> <C> <C>
Net Earnings as Reported . . . . . . . . . . . . . . . . . . . . $ 6.2 $ 9.7 $ 12.3 $ 15.8
Extraordinary Loss on Debt Extinguishments, Net of Income Tax
Benefit . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4.6 - 4.6 -
------ ------ ------ ------
Earnings Before Extraordinary Item . . . . . . . . . . . . . . . 10.8 9.7 16.9 15.8
------ ------ ------ ------
Significant Items Affecting Comparability, Pretax:
Income from receipt of contingency funds from an operator . . . 21.3 - 21.3 -
Charge for special incentive compensation strategy. . . . . . . (19.9) - (19.9) -
Income from retroactive severance tax refunds . . . . . . . . . - 0.2 - 1.8
Income from collection of Bolivian receivable . . . . . . . . . - 2.2 - 2.2
------ ------ ------ ------
Total Significant Items, Pretax. . . . . . . . . . . . . . . . 1.4 2.4 1.4 4.0
Income Tax Effect. . . . . . . . . . . . . . . . . . . . . . . 0.5 .7 0.5 1.2
------ ------ ------ ------
Total Significant Items, Aftertax. . . . . . . . . . . . . . . 0.9 1.7 0.9 2.8
------ ------ ------ ------
Net Earnings Excluding Significant Items and Extraordinary
Item. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $ 9.9 $ 8.0 $ 16.0 $ 13.0
====== ====== ====== ======
Earnings Per Share - Basic:
As reported . . . . . . . . . . . . . . . . . . . . . . . . . . $ 0.23 $ 0.36 $ 0.47 $ 0.60
Extraordinary loss. . . . . . . . . . . . . . . . . . . . . . . (0.17) - (0.17) -
Effect of other significant items . . . . . . . . . . . . . . . 0.03 0.06 0.04 0.11
------ ------ ------ ------
Excluding significant items and extraordinary item. . . . . . . $ 0.37 $ 0.30 $ 0.60 $ 0.49
====== ====== ====== ======
Earnings Per Share - Diluted:
As reported . . . . . . . . . . . . . . . . . . . . . . . . . . $ 0.23 $ 0.36 $ 0.46 $ 0.59
Extraordinary loss. . . . . . . . . . . . . . . . . . . . . . . (0.17) - (0.17) -
Effect of other significant items . . . . . . . . . . . . . . . 0.04 0.06 0.04 0.10
------ ------ ------ ------
Excluding significant items and extraordinary item. . . . . . . $ 0.36 $ 0.30 $ 0.59 $ 0.49
====== ====== ====== ======
</TABLE>
As shown above, excluding the significant items affecting comparability, net
earnings would have been $9.9 million ($0.37 per basic share, $0.36 per diluted
share) in the 1998 Quarter as compared to $8.0 million ($0.30 per basic and
diluted share) in the 1997 Quarter. The resulting increase in net earnings in
the 1998 Quarter was primarily attributable to improved refined product margins
combined with higher sales volumes in the Company's Refining and Marketing
segment and increased volumes of natural gas production in the Exploration and
Production segment, partially offset by higher corporate interest expense. For
the year-to-date periods, excluding significant items, net earnings would have
been $16.0 million ($0.60 per basic share, $0.59 per diluted share) for the 1998
Period compared to $13.0 million ($0.49 per basic and diluted share) for the
1997 Period. The increase in the 1998 Period was primarily due to better
refined product margins and higher sales volumes and increased natural gas
production volumes, partially offset by lower natural gas prices and higher
corporate interest expense and income tax provisions. A discussion and analysis
of the factors contributing to the Company's results of operations are presented
below.
14
<PAGE>
<TABLE>
<CAPTION>
REFINING AND MARKETING
Three Months Ended Six Months Ended
June 30, June 30,
--------------------- --------------------
1998 1997 1998 1997
---- ---- ---- ----
(Dollars in millions except per barrel amounts)
<S> <C> <C> <C> <C>
Gross Operating Revenues:
Refined products. . . . . . . . . . . . . . . . . . . . . . . . $ 184.9 $ 153.6 $ 307.6 $ 309.4
Other, primarily crude oil resales and merchandise. . . . . . . 22.7 8.2 40.2 26.8
-------- -------- -------- --------
Gross Operating Revenues . . . . . . . . . . . . . . . . . . . $ 207.6 $ 161.8 $ 347.8 $ 336.2
======== ======== ======== ========
Total Operating Profit:
Gross margin:
Refinery <F1>. . . . . . . . . . . . . . . . . . . . . . . . . $ 45.0 $ 25.4 $ 69.1 $ 44.1
Non-refinery <F2>. . . . . . . . . . . . . . . . . . . . . . . 15.1 10.5 24.7 16.5
-------- -------- -------- --------
Total gross margins . . . . . . . . . . . . . . . . . . . . . 60.1 35.9 93.8 60.6
Operating and other expenses. . . . . . . . . . . . . . . . . . 35.8 23.9 60.0 45.4
Depreciation and amortization . . . . . . . . . . . . . . . . . 4.3 3.2 7.3 6.3
-------- -------- -------- --------
Segment Operating Profit . . . . . . . . . . . . . . . . . . . $ 20.0 $ 8.8 $ 26.5 $ 8.9
======== ======== ======== ========
Capital Expenditures . . . . . . . . . . . . . . . . . . . . . . $ 5.2 $ 15.9 $ 7.2 $ 18.8
======== ======== ======== ========
Refinery Throughput (Barrels/day):
Alaska Refinery . . . . . . . . . . . . . . . . . . . . . . . . 59,996 52,409 58,082 50,785
Hawaii Refinery (for month of June 1998 only) <F3>. . . . . . . 63,676 - 63,676 -
% Alaska North Slope ("ANS") crude oil. . . . . . . . . . . . . 50% 82% 47% 80%
Total Refined Products Manufactured (average daily barrels)<F3>:
Gasoline and gasoline blendstocks . . . . . . . . . . . . . . . 20,675 13,276 17,957 13,082
Middle distillates, including jet fuel and diesel fuel. . . . . 35,416 22,074 30,315 21,620
Heavy oils and residual products. . . . . . . . . . . . . . . . 22,956 15,644 19,064 14,929
Other . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4,508 2,952 3,347 2,801
-------- -------- -------- --------
Total Refined Products Manufactured. . . . . . . . . . . . . . 83,555 53,946 70,683 52,432
======== ======== ======== ========
Total Refinery Product Spread ($/barrel) . . . . . . . . . . . . $ 6.11 $ 5.33 $ 5.56 $ 4.80
======== ======== ======== ========
Total Segment Product Sales (average daily barrels) <F3><F4>:
Gasoline. . . . . . . . . . . . . . . . . . . . . . . . . . . . 29,045 19,118 21,810 17,935
Middle distillates. . . . . . . . . . . . . . . . . . . . . . . 43,023 26,189 37,977 26,221
Heavy oils and residual products. . . . . . . . . . . . . . . . 25,927 21,507 22,139 19,708
-------- -------- -------- --------
Total Product Sales. . . . . . . . . . . . . . . . . . . . . . 97,995 66,814 81,926 63,864
======== ======== ======== ========
Total Segment Gross Margins on Product Sales ($/barrel) <F5>:
Average sales price . . . . . . . . . . . . . . . . . . . . . . $ 20.73 $ 25.26 $ 20.74 $ 26.76
Average costs of sales. . . . . . . . . . . . . . . . . . . . . 14.76 20.34 15.35 22.37
-------- -------- -------- --------
Gross Margin . . . . . . . . . . . . . . . . . . . . . . . . . $ 5.97 $ 4.92 $ 5.39 $ 4.39
======== ======== ======== ========
<FN>
<F1> Represents throughput at the Company's Alaska refinery ("Alaska Refinery") and Hawaii Refinery times
refinery product spread.
<F2> Non-refinery margin includes margins on products purchased and resold, margins on products sold in markets
outside of Alaska and Hawaii, intrasegment pipeline revenues, retail margins, and adjustments due to
selling a volume and mix of products that is different than actual volumes manufactured.
<F3> Sales and manufactured volumes for 1998 include amounts from the recently acquired Hawaii operations for
the month of June 1998, averaged over the periods presented. Throughput volumes for the Hawaii Refinery
are for the month of June 1998, averaged over the thirty-day month only.
<F4> Sources of total products sales include products manufactured at the refineries, products drawn from
inventory balances and products purchased from third parties. The Company's purchases of refined products
for resale averaged approximately 16,200 and 10,500 barrels per day for the three months ended June 30,
1998 and 1997, respectively, and 14,200 and 10,800 barrels per day for the six months ended June 30, 1998
and 1997, respectively.
<F5> Gross margins on total product sales include margins on sales of purchased products, together with the
effect of changes in inventories.
</TABLE>
15
<PAGE>
REFINING AND MARKETING
THREE MONTHS ENDED JUNE 30, 1998 COMPARED WITH THREE MONTHS ENDED JUNE 30, 1997.
Segment operating profit for the Company's Refining and Marketing operations was
$20.0 million in the 1998 Quarter, an increase of $11.2 million from segment
operating profit of $8.8 million in the 1997 Quarter. The improvement in
results from Refining and Marketing was due to a combination of factors,
including higher throughput volumes and improved refined product yields. In
addition, higher sales within the segment's Alaska and recently acquired Hawaii
markets (see Note B of Notes to Condensed Consolidated Financial Statements)
also contributed to the increase. The 1998 Quarter benefited from an expansion
completed in October 1997 of the Company's hydrocracker unit at the Alaska
Refinery, which increased the unit's capacity by approximately 25% and enables
the Company to produce more jet fuel, a product in short supply in Alaska. The
expansion began to favorably impact this segment's results in the fourth quarter
of 1997. The 1998 Quarter included results from refining and marketing
operations in Hawaii, which were acquired effective May 31, 1998. The Hawaii
operations contributed positively to the segment's results for the 1998 Quarter,
but are expected, after corporate interest expense, to have a neutral impact for
the year.
During the 1998 Quarter, throughput at the Alaska Refinery increased by 7,600
barrels per day, a 14% increase over the 1997 Quarter, resulting in a 19%
increase in middle distillate production from that refinery. Throughput at the
Hawaii Refinery, which was in a maintenance turnaround during part of the month
of June 1998, averaged 63,700 barrels per day during the month. The improved
Alaska product slate, together with results from the Hawaii operations,
contributed to an increase in the Company's total refinery product spread to
$6.11 per barrel in the 1998 Quarter, compared to $5.33 per barrel in the 1997
Quarter. Total product sales volumes increased by 31,200 barrels per day
primarily due to the acquisition of the Hawaii operations and higher throughput
volumes.
Revenues from sales of refined products increased during the 1998 Quarter
primarily due to higher sales volumes resulting from the Hawaii Acquisition and
higher throughput volumes, partially offset by a reduction in average sales
prices. Other revenues included crude oil resales of $13.3 million in the 1998
Quarter with no comparable sales in the 1997 Quarter. Merchandise revenues
increased in the 1998 Quarter due to the Hawaii Acquisition, which included 32
retail stations. The increase in costs of sales also reflected the higher
volumes associated with the Hawaii Acquisition and marketing efforts in Alaska
partly offset by lower feedstock prices. Margins from non-refinery activities
increased to $15.1 million in the 1998 Quarter due primarily to higher retail
sales and improved margins on products sold outside of Alaska and Hawaii.
Operating and other expenses increased during the 1998 Quarter due to the Hawaii
Acquisition and higher marketing costs in Alaska.
SIX MONTHS ENDED JUNE 30, 1998 COMPARED WITH SIX MONTHS ENDED JUNE 30, 1997.
Segment operating profit from the Refining and Marketing operations totaled
$26.5 million in the 1998 Period compared to segment operating profit of $8.9
million in the 1997 Period. As discussed above, this increase was due to a
number of factors, including higher throughput volumes, improved refined product
yields and higher sales volumes within the segment's core Alaska and Hawaii
markets.
During the 1998 Period, throughput at the Alaska Refinery increased by 7,300
barrels per day, a 14% increase over the 1997 Period, resulting in a 19%
increase in middle distillates production from that refinery. The improved
product slate, together with the Hawaii operations, contributed to an increase
in the Company's total refinery product spread to $5.56 per barrel in the 1998
Period, compared to $4.80 per barrel in the 1997 Period. Total product sales
volumes increased by 18,100 barrels per day during the 1998 Period.
Revenues from sales of refined products in the Company's Refining and Marketing
segment decreased during the 1998 Period as lower sales prices more than offset
the effect of higher sales volumes. Other revenues included $23.8 million and
$10.7 million in crude oil resales in the 1998 Period and 1997 Period,
respectively. The decrease in cost of sales was primarily due to lower
feedstock costs partially offset by higher volumes. Margins on non-refinery
activities increased to $24.7 million in the 1998 Period as compared to $16.5
million in the 1997 Period due primarily to higher retail sales and improved
margins on products sold outside of Alaska and Hawaii. Operating and other
expenses were higher in the 1998 Period due to the Hawaii Acquisition and higher
marketing costs in Alaska.
The Company's initiatives to enhance its product slate and sell more product
within core markets have improved the fundamental earnings potential of this
segment. Certain of these initiatives, such as the Alaska hydrocracker
expansion, were completed in the fourth quarter of 1997. Future quarters will
continue to benefit from the impact of these initiatives. In addition, Tesoro
expects that the results of the Acquisitions will be accretive to earnings and
cash flows beginning in 1999. The revenues and scope of the Refining and
Marketing segment will be significantly increased with the Acquisitions (see
Note B of Notes to Condensed Consolidated Financial Statements). Future
profitability of this segment, however, will continue to be influenced by market
conditions, particularly as these conditions influence costs of crude oil
relative to prices received for sales of refined products, and other additional
factors that are beyond the control of the Company.
16
<PAGE>
<TABLE>
<CAPTION>
EXPLORATION AND PRODUCTION
Three Months Ended Six Months Ended
June 30, June 30,
------------------ ------------------
1998 1997 1998 1997
---- ---- ---- ----
(Dollars in millions except per unit amounts)
<S> <C> <C> <C> <C>
U.S. <F1>:
Gross operating revenues . . . . . . . . . . . . . . $ 18.7 $ 15.9 $ 37.8 $ 37.4
Other income . . . . . . . . . . . . . . . . . . . . 21.7 0.3 22.3 1.9
Production costs . . . . . . . . . . . . . . . . . . 2.0 1.8 4.5 3.5
Administrative support and other operating expenses. 0.6 0.6 1.0 1.1
Depreciation, depletion and amortization . . . . . . 9.3 7.3 18.2 15.2
------- ------- ------- -------
Segment Operating Profit - U.S. . . . . . . . . . . 28.5 6.5 36.4 19.5
------- ------- ------- -------
BOLIVIA:
Gross operating revenues . . . . . . . . . . . . . . 2.9 2.7 6.0 4.6
Other income (expense) . . . . . . . . . . . . . . . (0.5) 2.2 (0.5) 2.2
Production costs . . . . . . . . . . . . . . . . . . 0.2 0.2 0.5 0.4
Administrative support and other operating expenses. 0.8 0.3 1.4 0.8
Depreciation, depletion and amortization . . . . . . 0.7 0.3 1.2 0.5
------- ------- ------- -------
Segment Operating Profit - Bolivia. . . . . . . . . 0.7 4.1 2.4 5.1
------- ------- ------- -------
Total Segment Operating Profit - Exploration and
Production. . . . . . . . . . . . . . . . . . . . . $ 29.2 $ 10.6 $ 38.8 $ 24.6
======= ======= ======= =======
U.S.:
Average Daily Net Production:
Natural gas (thousand cubic feet, "Mcf"). . . . . . 93,086 85,324 96,094 89,689
Oil (barrels) . . . . . . . . . . . . . . . . . . . 257 121 215 133
Total (thousand cubic feet equivalent, "Mcfe") . . 94,628 86,050 97,384 90,487
Average Prices:
Natural gas ($/Mcf) <F2>. . . . . . . . . . . . . . $ 2.06 $ 1.85 $ 2.04 $ 2.11
Oil ($/barrel). . . . . . . . . . . . . . . . . . . $ 12.66 $ 18.38 $ 13.25 $ 19.87
Average Operating Expenses ($/Mcfe):
Lease operating expenses. . . . . . . . . . . . . . $ 0.22 $ 0.19 $ 0.21 $ 0.17
Severance taxes . . . . . . . . . . . . . . . . . . 0.01 0.04 0.04 0.04
------- ------- ------- -------
Total production costs . . . . . . . . . . . . . . 0.23 0.23 0.25 0.21
Administrative support and other. . . . . . . . . . 0.06 0.06 0.05 0.06
------- ------- ------- -------
Total Operating Expenses . . . . . . . . . . . . . $ 0.29 $ 0.29 $ 0.30 $ 0.27
======= ======= ======= =======
Depletion ($/Mcfe) . . . . . . . . . . . . . . . . . $ 1.06 $ 0.93 $ 1.01 $ 0.92
======= ======= ======= =======
Capital Expenditures . . . . . . . . . . . . . . . . $ 20.3 $ 9.2 $ 38.5 $ 16.2
======= ======= ======= =======
BOLIVIA:
Average Daily Net Production:
Natural gas (Mcf) . . . . . . . . . . . . . . . . . 26,458 17,326 24,624 14,180
Condensate (barrels). . . . . . . . . . . . . . . . 724 506 770 412
Total (Mcfe) . . . . . . . . . . . . . . . . . . . 30,802 20,362 29,244 16,652
Average Prices:
Natural gas ($/Mcf) . . . . . . . . . . . . . . . . $ 0.83 $ 1.25 $ 0.90 $ 1.28
Condensate ($/barrel) . . . . . . . . . . . . . . . $ 12.90 $ 16.21 $ 14.42 $ 17.38
Average Operating Expenses ($/Mcfe):
Production costs. . . . . . . . . . . . . . . . . . $ 0.10 $ 0.09 $ 0.10 $ 0.12
Administrative support and other. . . . . . . . . . 0.25 0.24 0.27 0.30
------- ------- ------- -------
Total Operating Expenses . . . . . . . . . . . . . $ 0.35 $ 0.33 $ 0.37 $ 0.42
======= ======= ======= =======
Depletion ($/Mcfe) . . . . . . . . . . . . . . . . . $ 0.22 $ 0.16 $ 0.22 $ 0.16
======= ======= ======= =======
Capital Expenditures . . . . . . . . . . . . . . . . $ 9.2 $ 2.0 $ 11.5 $ 6.0
======= ======= ======= =======
<FN>
<F1> Represents the Company's U.S. oil and gas operations combined with gas transportation
activities.
<F2> Includes effects of the Company's natural gas commodity price agreements which amounted to
gains of $0.02 per Mcf and $0.01 per Mcf for the three months and six months ended June 30,
1998, respectively, and a loss of $0.10 per Mcf for the six months ended June 30, 1997. There
were no such gains or losses during the three months ended June 30, 1997.
</TABLE>
17
<PAGE>
EXPLORATION AND PRODUCTION
U.S.
THREE MONTHS ENDED JUNE 30, 1998 COMPARED WITH THREE MONTHS ENDED JUNE 30, 1997.
Segment operating profit from the Company's U.S. exploration and production
operations was $28.5 million in the 1998 Quarter compared with $6.5 million in
the 1997 Quarter. The 1998 Quarter benefited from receipt of approximately
$21.3 million from an operator in the Bob West Field, representing funds that
are no longer needed as a contingency reserve for litigation. Excluding the
receipt of those funds and other items, segment operating profit increased by
approximately $0.9 million during the 1998 Quarter primarily due to recent
drilling success and higher natural gas prices. The Company's U.S. production
volumes increased by 10% and natural gas prices increased by $0.21 per Mcf, or
11%, to $2.06 per Mcf in the 1998 Quarter from $1.85 per Mcf in the 1997
Quarter.
The Company's U.S. production volumes averaged 94.6 million cubic feet
equivalents ("Mmcfe") per day in the 1998 Quarter compared to 86.1 Mmcfe per day
in the 1997 Quarter. The Company's U.S. production outside of the Bob West
Field rose to 52% of total U.S. production during the 1998 Quarter, as compared
to 18% in the 1997 Quarter. This increase was attributable to the development
of fields discovered in the Val Verde Basin, the Upper Wilcox Trend and the
Frio/Vicksburg Trend.
Gross operating revenues from the Company's U.S. operations increased by $2.8
million, due to higher spot market prices for sales of natural gas and increased
production volumes. Other income in the 1998 Quarter included the receipt of
funds from an operator discussed above. Production costs per Mcfe remained flat
at $0.23 per Mcfe, while total production costs increased by $0.2 million due to
higher volumes. Depreciation, depletion and amortization increased by $2.0
million, or 27%, due to a higher depletion rate and increased volumes.
From time to time, the Company enters into commodity price agreements to reduce
the risk caused by fluctuation in the prices of natural gas in the spot market.
During the 1998 Quarter, the Company used such agreements to set the price of
approximately 18% of the natural gas production that it sold in the spot market
and recognized a gain of $0.2 million ($0.02 per Mcf) related to these price
agreements. The Company did not have any such transactions during the 1997
Quarter.
SIX MONTHS ENDED JUNE 30, 1998 COMPARED WITH SIX MONTHS ENDED JUNE 30, 1997.
Segment operating profit of $36.4 million from the Company's U.S. exploration
and production operations in the 1998 Period compares to $19.5 million in the
1997 Period. Comparability between these periods was impacted by certain
significant items. The 1997 Period included retroactive severance tax refunds
of $1.8 million, while the 1998 Period included income from receipt of
approximately $21.3 million from an operator in the Bob West Field, discussed
above. Excluding these significant items, segment operating profit decreased by
approximately $2.6 million primarily due to lower natural gas prices and higher
depreciation, depletion and amortization.
Prices realized by the Company on its spot natural gas production declined by 3%
to $2.04 per Mcf in the 1998 Period from $2.11 per Mcf in the 1997 Period. The
Company's U.S. production averaged 97.4 Mmcfe per day in the 1998 Period, an
increase of 6.9 Mmcfe per day over the 1997 Period.
Gross operating revenues from the Company's U.S. operations increased by $0.4
million as higher production volumes were generally offset by lower prices.
Production costs were higher by $1.0 million, primarily due to higher lease
operating expenses. Lease operating costs increased from $0.17 per Mcfe in the
1997 Period to $0.21 per Mcfe in the 1998 Period. Depreciation, depletion and
amortization increased by $3.0 million, or 20%, due to a higher depletion rate
and increased volumes.
During the 1998 and 1997 Periods, the Company used commodity price agreements to
set the price of approximately 9% and 17%, respectively, of the natural gas
production that it sold in the spot market. During the 1998 and 1997 Periods,
the Company realized a gain of $0.2 million ($0.01 per Mcf) and a loss of $1.6
million ($0.10 per Mcf), respectively, from these price agreements.
BOLIVIA
THREE MONTHS ENDED JUNE 30, 1998 COMPARED WITH THREE MONTHS ENDED JUNE 30, 1997.
Segment operating profit from the Company's Bolivian operations decreased $3.4
million from $4.1 million in the 1997 Quarter to $0.7 million in the 1998
Quarter. The 1997 Quarter included other income of $2.2 million related to the
collection of a receivable for production in prior periods. Excluding this
other income, segment operating profit decreased by $1.2
18
<PAGE>
million during the 1998 Quarter due to a decline in natural gas prices together
with a charge for prior period taxes. Bolivian natural gas prices, which are
contractually tied to posted New York fuel oil prices, fell 33% from $1.25 per
Mcf in the 1997 Quarter to $0.83 per Mcf in the 1998 Quarter. However,
production volumes increased from 20.4 Mmcfe per day to 30.8 Mmcfe per day
resulting in an overall revenue increase of $0.2 million. The production
increase was due in part to the July 1997 buyout of interests held by the
Company's former joint venture participant, increasing its share of net
production by approximately 33%. The increase in depreciation, depletion and
amortization was due to higher production volumes and a higher depletion rate.
SIX MONTHS ENDED JUNE 30, 1998 COMPARED WITH SIX MONTHS ENDED JUNE 30, 1997.
Segment operating profit from the Company's Bolivian operations decreased $2.7
million from $5.1 million in the 1997 Period to $2.4 million in the 1998 Period.
The 1997 Period included other income of $2.2 million related to the collection
of the receivable discussed above. Excluding this other income, segment
operating profit for the 1998 Period decreased by $0.5 million from the 1997
Period. Bolivian natural gas prices fell 30% from $1.28 per Mcf in the 1997
Period to $0.90 per Mcf in the 1998 Period and condensate prices fell from
$17.38 to $14.42 per barrel. However, production volumes increased from 16.7
Mmcfe per day to 29.2 Mmcfe per day resulting in an overall revenue increase of
$1.4 million. The Company's share of net production increased by approximately
33% in the 1998 Period as a result of the July 1997 buyout of interests held by
its former joint venture participant, and the remaining production difference
resulted in part from production constraints in the 1997 Period arising from
repairs to a non-Company-owned pipeline that transports gas from Bolivia to
Argentina. The increase in depreciation, depletion and amortization was due to
higher production volumes and a higher depletion rate.
A lack of market access has constrained natural gas production in Bolivia. The
Company believes that the completion of a 1,900-mile pipeline from Bolivia to
Brazil will provide access to larger gas-consuming markets. Upon completion of
this pipeline, the Company will face intense competition from major and
independent natural gas companies operating in Bolivia for a share of the
contractual volumes to be exported to Brazil. It is anticipated that each
producer's share of the contractual volumes will be allocated by YPFB according
to a number of factors, including the producer's reserve volumes and production
capacity. Although the Company expects gas deliveries on the pipeline to begin
in early 1999, there can be no assurance that the pipeline will be operational
by such date. With the exception of the volumes currently under contract with
the Bolivian government, the Company cannot be assured of the amount of
additional volumes that will be exported to Brazil upon completion of the
pipeline.
The productive capacity of the Company's wells in Bolivia, including shut-in
wells, is approximately 120 Mmcf per day gross. The Company spudded two wells
during the second quarter of 1998 as part of a five-well program designed to
increase proved reserves. In addition, an affiliate of Total, S.A. has spud the
first well pursuant to a farmout agreement covering the Company's acreage
located in the Andes mountains.
19
<PAGE>
<TABLE>
<CAPTION>
MARINE SERVICES
Three Months Ended Six Months Ended
June 30, June 30,
------------------ -----------------
1998 1997 1998 1997
---- ---- ---- ----
(Dollars in Millions)
<S> <C> <C> <C> <C>
Gross Operating Revenues:
Fuels . . . . . . . . . . . . . . . . . $ 22.5 $ 24.2 $ 48.3 $ 52.4
Lubricants and other. . . . . . . . . . 3.8 3.8 7.9 8.1
Services. . . . . . . . . . . . . . . . 2.8 2.3 5.7 5.3
----- ----- ----- -----
Gross Operating Revenues . . . . . . . 29.1 30.3 61.9 65.8
Costs of Sales . . . . . . . . . . . . . 19.8 22.4 43.4 49.7
----- ----- ----- -----
Gross Profit . . . . . . . . . . . . . 9.3 7.9 18.5 16.1
Operating and Other Expenses . . . . . . 7.2 7.0 14.0 13.9
Depreciation and Amortization. . . . . . 0.5 0.4 1.1 0.8
----- ----- ----- -----
Segment Operating Profit. . . . . . . $ 1.6 $ 0.5 $ 3.4 $ 1.4
===== ===== ===== =====
Sales Volumes (millions of gallons):
Fuels, primarily diesel . . . . . . . . 43.6 37.5 91.5 77.1
Lubricants. . . . . . . . . . . . . . . 0.5 0.7 1.2 1.3
Capital Expenditures . . . . . . . . . . $ 1.4 $ 1.1 $ 2.6 $ 3.3
</TABLE>
Gross operating revenues declined by $1.2 million and $3.9 million during the
1998 Quarter and 1998 Period, respectively, primarily due to lower fuel sales
prices, partially offset by increased fuel volumes,. The decreases in costs of
sales also reflected the lower fuel prices. In total, segment operating profit
improved by $1.1 million and $2.0 million in the 1998 Quarter and 1998 Period,
respectively, largely due to increased margins.
The Marine Services segment's business is largely dependent upon the volume of
oil and gas drilling, workover, construction and seismic activity in the Gulf of
Mexico.
INTEREST EXPENSE
Interest expense increased by $4.2 million and $5.3 million during the 1998
Quarter and 1998 Period, respectively. These increases were primarily due to
higher borrowings under the Company's credit arrangements to fund the Hawaii
Acquisition and the Refinancing (see Notes B and C of Notes to Condensed
Consolidated Financial Statements), together with borrowings to fund net working
capital requirements and capital expenditures.
OTHER OPERATING COSTS AND OTHER EXPENSES
Other operating costs and other expense for the 1998 Quarter and 1998 Period
included a charge of $19.9 million for the special incentive compensation
strategy, of which $7.9 million related to operating segment employees (see Note
F of Notes to Condensed Consolidated Financial Statements).
INCOME TAX PROVISION
The income tax provision increased by $2.8 million and $4.1 million in the 1998
Quarter and 1998 Period, respectively, resulting in effective tax rates of 43%
in 1998 and 36% in 1997. The increase in the effective tax rate was primarily
due to higher foreign taxes on the Company's increased Bolivian revenues and
higher consolidated earnings which reduced available net operating loss
carryforwards.
20
<PAGE>
CAPITAL RESOURCES AND LIQUIDITY
OVERVIEW
The Company's primary sources of liquidity are its cash and cash equivalents,
internal cash generation and external financing. The Company operates in an
environment where its liquidity and capital resources are impacted by changes in
the supply of and demand for crude oil, natural gas and refined petroleum
products, market uncertainty and a variety of additional risks that are beyond
the control of the Company. These risks include, among others, the level of
consumer product demand, weather conditions, the proximity of the Company's
natural gas reserves to pipelines, the capacities of such pipelines,
fluctuations in seasonal demand, governmental regulations, the price and
availability of alternative fuels and overall market and economic conditions.
The Company's future capital expenditures as well as borrowings under its credit
arrangements and other sources of capital will be affected by these conditions.
CREDIT ARRANGEMENTS AND CAPITALIZATION
Refinancing and Offerings
In conjunction with closing the Hawaii Acquisition, on May 29, 1998, Tesoro
completed a Refinancing of all of its then-existing indebtedness. The total
amount of funds required by Tesoro to complete the Hawaii Acquisition and the
Refinancing, to pay related fees and expenses and for general corporate purposes
was approximately $432 million, which was financed through the Interim Credit
Facility. Subsequent to June 30, 1998, the Company refinanced all borrowings
under the Interim Credit Facility with net proceeds from the Offerings and
borrowings under the Senior Credit Facility.
On July 2, 1998, and in connection with the Notes Offering and the Washington
Acquisition, the Company entered into the Senior Credit Facility in the amount
of $500 million. In addition to funding the cash consideration of the
Acquisitions and Refinancing, the Senior Credit Facility will provide the
Company with enhanced financial flexibility, such as increased working capital
capacity and funds for general corporate purposes, including the capital
expenditures projected for 1998.
On May 4, 1998, the Company filed a Universal Shelf Registration Statement with
the SEC for $600 million of debt or equity securities for acquisitions or
general corporate purposes. The Universal Shelf Registration Statement was
declared effective by the SEC on May 14, 1998. The Company offered PIES and
Common Stock from the Universal Shelf Registration Statement to provide partial
funding for the Acquisitions. On July 1, 1998, the Company issued 9,000,000
PIES, representing fractional interests in the Company's 7.25% Mandatorily
Convertible Preferred Stock, with gross proceeds of approximately $143.4
million, and 5,000,000 shares of Common Stock, with gross proceeds of $79.7
million. Upon exercise of the over-allotment options granted to the underwiters
of the Equity Offerings, on July 8, 1998, the Company issued 1,350,000 PIES with
gross proceeds of $21.5 million and 750,000 shares of Common Stock with gross
proceeds of $11.9 million. Holders of PIES are entitled to receive a cash
dividend. The PIES will automatically convert into shares of Common Stock on
July 1, 2001, at a rate based upon a formula dependent upon the market price of
Common Stock. Before July 1, 2001, each PIES is convertible, at the option of
the holder thereof, into 0.8455 shares of Common Stock, subject to adjustment in
certain events.
On July 2, 1998, concurrently with the syndication of the Senior Credit
Facility, the Company issued $300 million aggregate principal amount of Senior
Subordinated Notes through a private offering eligible for Rule 144A. The Senior
Subordinated Notes have a ten-year maturity without sinking fund requirements
and are subject to optional redemption by the Company after five years at
declining premiums. On August 7, 1998, a Registration Statement was declared
effective by the SEC whereby the Company is offering, upon the terms and subject
to the conditions set forth in the related Prospectus, to exchange $1,000
principal amount of Exchange Notes for each $1,000 principal amount of its
Senior Subordinated Notes. The terms of the Exchange Notes are identical in all
material respects to the terms of the Senior Subordinated Notes, except as
described in the Prospectus.
See Changes in Securities and Use of Proceeds in Part II, Item 2, and Note C of
Notes to Condensed Consolidated Financial Statements for information related to
the Senior Credit Facility, Senior Subordinated Notes and PIES, including
restrictions on dividends.
Capitalization
Upon issuance of the Senior Subordinated Notes, Common Stock and PIES, entering
into the Senior Credit Facility and the application of the estimated net
proceeds therefrom, the Company's pro forma indebtedness as of June 30,
21
<PAGE>
1998 would have been approximately $484 million (excluding an additional $348
million available under the Senior Credit Facility) with a
debt-to-capitalization ratio of 45%. Historically, total indebtedness at June
30, 1998 was $454 million, with a debt-to-capitalization ratio of 56%.
The Company's primary capital requirements are expected to include capital
expenditures, working capital and debt service. The primary sources of capital
are expected to be cash flow from operations and borrowings under the Senior
Credit Facility which incurs interest at variable rates. Based upon current and
anticipated needs, the Company believes that available capital resources will be
adequate to meet anticipated future capital requirements.
The Senior Credit Facility, the Senior Subordinated Notes and PIES, as described
in Note C of Notes to Condensed Consolidated Financial Statements and in Part
II, Item 2, impose various restrictions and covenants on the Company that could
potentially limit the Company's ability to respond to market conditions, to
provide for unanticipated capital investments, to raise additional debt or
equity capital or to take advantage of business opportunities.
CAPITAL SPENDING (EXCLUDING AMOUNTS TO FUND ACQUISITIONS)
For the year 1998, the Company's capital spending is projected to total $222
million, which includes estimated capital expenditures for the operations
recently acquired. Capital expenditures for 1998 are expected to be financed
through a combination of cash flows from operations, available cash reserves and
additional borrowings under credit arrangements. Actual capital expenditures
may vary from these projections due to a number of factors, including the timing
of drilling projects and the extent to which properties are acquired. During
the 1998 Period, the Company's capital expenditures totaled $62 million which
were financed primarily with external financing and internally-generated cash
flows.
The Exploration and Production segment accounts for $138 million of the
projected capital spending with $88 million planned for U.S. activities and $50
million for Bolivia. Planned U.S. expenditures include $20 million for
acquisitions, $26 million for development drilling (participation in 25 wells),
$14 million for leasehold, geological and geophysical, and $23 million for
exploratory drilling (participation in 25 wells). In Bolivia, the drilling
program is projected at $13 million for development drilling (two wells) and $18
million for exploratory drilling (three wells), with the remainder planned for
gathering lines to shut-in wells, workovers and three-dimensional seismic
activity. For the 1998 Period, actual U.S. expenditures in the Exploration and
Production segment were $38 million, principally for the participation in the
drilling of eleven development wells (ten completed) and eleven exploratory
wells (five completed). In Bolivia, capital spending for the 1998 Period
totaled $12 million, primarily for drilling two wells in progress.
Capital spending for the Refining and Marketing segment is planned at $66
million for the year 1998, which includes $25 million for retail marketing, $23
million for improvements to the refineries and $12 million for environmental
projects. The Refining and Marketing segment spent approximately $7 million
towards these projects during the 1998 Period. The Marine Services capital
projections are $6 million for the year 1998, of which $3 million was spent
during the 1998 Period, and are primarily directed towards equipment and
facility upgrades. Remaining capital projections of approximately $12 million
are primarily related to corporate projects, including installation and
implementation of an integrated software system and other upgrades.
CASH FLOWS
Components of the Company's cash flows are set forth below (in millions):
<TABLE>
<CAPTION>
Six Months Ended
June 30,
----------------
1998 1997
---- ----
<S> <C> <C>
Cash Flows From (Used In):
Operating Activities . . . . . . . . . . . . . . . $ 43.9 $ 57.4
Investing Activities . . . . . . . . . . . . . . . (315.6) (45.0)
Financing Activities . . . . . . . . . . . . . . . 289.7 (0.3)
------- -------
Increase in Cash and Cash Equivalents. . . . . . . . $ 18.0 $ 12.1
======= =======
</TABLE>
Net cash from operating activities of $44 million during the 1998 Period,
compared to $57 million during the 1997 Period. Although the level of earnings
during both periods was relatively comparable, working capital components
22
<PAGE>
were higher during the 1998 Period primarily due to the increased refining and
marketing activities. Net cash used in investing activities of $316 million
during the 1998 Period included approximately $243 million for the Hawaii
Acquisition, capital expenditures of $62 million, and an escrow deposit of $5
million for the Washington Acquisition. Net cash from financing activities of
$290 million included gross borrowings under revolving credit lines of $421
million, with $28 million of repayments, offset by the refinancing and payment
of other debt. At June 30, 1998, the Company's net working capital totaled $162
million, which included cash and cash equivalents of $26 million.
ENVIRONMENTAL AND OTHER
The Company is subject to extensive federal, state and local environmental laws
and regulations. These laws, which change frequently, regulate the discharge of
materials into the environment and may require the Company to remove or mitigate
the environmental effects of the disposal or release of petroleum or chemical
substances at various sites or install additional controls or other
modifications or changes in use for certain emission sources. The Company is
currently involved in remedial responses and has incurred cleanup expenditures
associated with environmental matters at a number of sites, including certain of
its current and prior-owned properties. At June 30, 1998, the Company's
accruals for environmental expenses amounted to $10.9 million, which includes
approximately $2.5 million for remediation of KPL's properties (funded by the
former owners of KPL through a restricted escrow deposit). Based on currently
available information, including the participation of other parties or former
owners in remediation actions, the Company believes these accruals are adequate.
In addition to environmental expenses, the Company anticipates that it will make
capital improvements of approximately $10 million in 1998 and $5 million in 1999
to comply with environmental laws and regulations affecting its Alaska, Hawaii
and Gulf Coast operations. In addition, capital expenditures for alternative
secondary containment systems for existing storage tank facilities in Alaska are
estimated to be $2 million in 1998 and $2 million in 1999, with a remaining $5
million to be spent by 2002.
Conditions that require additional expenditures may exist for various Company
sites, including, but not limited to, the Company's refineries, retail stations
(current and closed locations) and petroleum product terminals, and for
compliance with the Clean Air Act. The amount of such future expenditures cannot
currently be determined by the Company. For further information on
environmental contingencies, including environmental matters related to the
Acquisitions, see Note E of Notes to Condensed Consolidated Financial Statements
and Legal Proceedings in Part II, Item 1, included herein.
The Company's results for the 1998 Quarter and Period reflected receipt of
approximately $21 million pretax ($14 million aftertax) from an operator in the
Bob West Field, representing funds that are no longer needed as a contingency
reserve for litigation. These proceeds were used to reduce debt levels.
YEAR 2000 COMPLIANCE
The efficient operation of the Company's business is dependent on its computer
hardware, operating systems and software programs (collectively, "Systems and
Programs"). These Systems and Programs are used in several key areas of the
Company's business, including information management services and financial
reporting, as well as in various administrative functions. The Company has been
evaluating its Systems and Programs to identify potential year 2000 compliance
problems, as well as manual processes, external interfaces with customers and
services supplied by vendors to coordinate year 2000 compliance and conversion.
The year 2000 problem refers to the limitations of certain existing hardware and
software programs to recognize date sensitive information for the year 2000 and
beyond. Unless replaced or modified prior to the year 2000, such hardware and
systems may not properly recognize such information and could generate erroneous
data or cause a system to fail to operate properly. Based on current
information, the Company expects to attain year 2000 compliance and institute
appropriate testing of its modifications and replacements in a timely fashion
and in advance of the year 2000 date change. It is anticipated that
modification or replacement of the Company's Systems and Programs will be
performed in-house by company personnel as well as external consultants.
The Company believes that, with hardware replacement and modifications to
existing software or conversions to new software, the year 2000 date change will
not pose a significant operational problem for the Company. However, because
most computer systems are, by their very nature, interdependent, it is possible
that non-compliant third party computer systems or programs may not interface
properly with the Company's computer systems. The Company has requested
assurance from third parties that their computers, systems or programs be year
2000 compliant. The
23
<PAGE>
Company could, however, be adversely affected by the year 2000 problem if it or
unrelated parties fail to successfully address this issue.
Management of the Company currently anticipates that the expenses and capital
expenditures associated with the year 2000 compliance project will not have a
material effect on its business financial condition or results of operations.
The costs of year 2000 compliance and the expected completion dates are the best
estimates of Company management and are believed to be reasonably accurate. In
the event the Company's plan to address the year 2000 problem is not
successfully or timely implemented, the Company may need to devote more
resources to the process and additional costs may be incurred. Problems
encountered by the Company's vendors, customers and other third parties may also
have an adverse effect on the Company's operations. Purchased hardware and
software has been and will continue to be capitalized in accordance with normal
accounting policy. Personnel and other costs will also be accounted for as
appropriate under normal accounting policy.
The Company has recently undertaken a review of the year 2000 compliance status
of BHP Hawaii and Shell Washington, and is currently unable to determine whether
it has exposure to contingencies related to the year 2000 issue in connection
with the Acquisitions.
NEW ACCOUNTING STANDARDS
In February 1998, the Financial Accounting Standards Board ("FASB") issued SFAS
No. 132, "Employers' Disclosures about Pensions and Other Postretirement
Benefits," which standardizes the disclosures related to pensions and other
postretirement benefits to the extent practicable, requires additional
information on changes in the benefit obligations and fair values of plan assets
and eliminates certain disclosures previously required. SFAS No. 132 becomes
effective for the Company in 1998 and contains provisions for restatement of
prior period information. In June 1998, the FASB issued SFAS No. 133,
"Accounting for Derivative Instruments and Hedging Activities," which
establishes accounting and reporting standards for derivative instruments,
including certain derivative instruments embedded in other contracts and for
hedging activities. SFAS No. 133 requires that an entity recognize all
derivatives as either assets or liabilities in the statement of financial
position and measure those instruments at fair value. The accounting for
changes in the fair value of a derivative depends on the intended use of the
derivative and the resulting designation. SFAS No. 133 is effective for all
quarters of fiscal years beginning after June 15, 1999 and should not be applied
retroactively to financial statements of prior periods. The Company is
evaluating the effects that these new statements will have on its financial
condition, results of operations and financial reporting and disclosures.
FORWARD-LOOKING STATEMENTS
This Quarterly Report on Form 10-Q contains certain statements that are
"forward-looking" statements within the meaning of Section 27A of the Securities
Act of 1933, as amended (the "Securities Act") and Section 21E of the Securities
and Exchange Act of 1934, as amended (the "Exchange Act"). These
forward-looking statements include, among other things, discussions of
anticipated revenue enhancements and cost savings following the Acquisitions,
the Company's business strategy and expectations concerning the Company's market
position, future operations, margins, profitability, liquidity and capital
resources, expenditures for capital projects and attempts to reduce costs.
Although the Company believes that the assumptions upon which the
forward-looking statements contained in this Form 10-Q are based are reasonable,
any of the assumptions could prove to be inaccurate and, as a result, the
forward-looking statements based on those assumptions also could be incorrect.
All phases of the operations of the Company involve risks and uncertainties,
many of which are outside the control of the Company and any one of which, or a
combination of which, could materially affect the results of the Company's
operations and whether the forward-looking statements ultimately prove to be
correct. Actual results and trends in the future may differ materially
depending on a variety of factors including, but not limited to, the timing and
extent of changes in commodity prices and underlying demand and availability of
crude oil and other refinery feedstocks, refined products, and natural gas;
changes in the cost or availability of third-party vessels, pipelines and other
means of transporting feedstocks and products; execution of planned capital
projects; adverse changes in the credit ratings assigned to the Company's trade
credit; future well performance; the extent of the Company's success in
acquiring oil and gas properties and in discovering, developing and producing
reserves; state and federal environmental, economic, safety and other policies
and regulations, any changes therein, and any legal or regulatory delays or
other factors beyond the Company's control; adverse rulings, judgments, or
settlements in litigation or other legal matters, including unexpected
environmental remediation costs in excess of any reserves; actions of customers
and competitors; weather conditions affecting the Company's operations or the
areas in which the Company's products are marketed; earthquakes or other natural
disasters affecting operations; political developments in foreign countries; and
the conditions of the capital markets and equity markets during the periods
covered by the forward-looking statements. Future results will also
24
<PAGE>
be dependent upon the ability of the Company to integrate the Acquisitions with
the Company's other operations. Many of the factors are described in greater
detail in the Company's Annual Report on Form 10-K for the year ended December
31, 1997, and other of the Company's filings with the SEC. All subsequent
written and oral forward-looking statements attributable to the Company or
persons acting on its behalf are expressly qualified in their entirety by the
foregoing. The Company undertakes no obligation to publicly release the result
of any revisions to any such forward-looking statements that may be made to
reflect events or circumstances after the date hereof or to reflect the
occurrence of unanticipated events.
25
<PAGE>
PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
The Hawaii Department of Health ("HDOH"), under authority of the Hawaii
Environmental Response Law, has undertaken an investigation of
environmental conditions within a portion of the Honolulu Harbor area,
which has been designated the Iwilei Unit, to determine the extent of
hydrocarbon contamination. A group of owners and operators at the Iwilei
Unit, including BHP Hawaii, have entered into a voluntary agreement with
the HDOH to undertake an initial phase of environmental site investigation
within the Iwilei Unit in exchange for certain commitments from the HDOH,
including the notification of additional PRPs to participate in this
activity. The costs associated with this proceeding cannot be determined
at this early stage. BHP Hawaii owned and operated facilities in the
Iwilei Unit, including, but not limited to the Pier 29 terminal facilities
(which were returned, upon expiration of the lease term, to the State of
Hawaii Department of Transportation) and the Pier 34 terminal facilities
(which are now owned and operated by the Company under a lease with the
same agency). Under the indemnity provisions of the environmental
agreement between the BHP Sellers and the Company, the Company is fully
indemnified for claims arising out of this proceeding as it relates to the
Iwilei Unit by affiliates of BHP and this indemnity is not subject to the
$9.5 million cap or ten-year claim period.
The EPA issued a Notice of Violation ("NOV") on June 24, 1997, against the
Hawaii Refinery alleging violations of the Clean Water Act associated with
the content and implementation of the refinery's Spill Prevention, Control
and Countermeasures ("SPCC") Plan, and further alleging violations based on
a series of oil releases. The Company and the EPA remain engaged in
settlement discussions with remaining issues limited to alleged
deficiencies in the content and implementation of the refinery Spill
Prevention, Control and Countermeasures Plan. This proceeding is subject
to the indemnity provision of the environmental agreement between the BHP
Sellers and the Company.
Also on June 24, 1997, a NOV was issued against BHP companies pursuant to
Section 103 of the Comprehensive Environmental Response, Compensation and
Liability Act ("CERCLA") and Section 304 of the Emergency Planning and
Community Right to Know Act ("EPCRA") regarding past releases of reportable
quantities of regulated substances and oil. This matter remains subject to
EPA review and penalty amounts have not been assessed to date. This
proceeding is subject to the indemnity provisions of the environmental
agreement between the BHP Sellers and the Company.
On August 5, 1996, the EPA issued a Finding of Violation ("FOV") against
BHP Hawaii pursuant to disclosures made by BHP Hawaii pursuant to a permit
application for compliance with Title V of the Clean Air Act. The parties
have engaged in settlement negotiations and no penalty amount has been
assessed. This proceeding is subject to the indemnity provision of the
environmental agreement between affiliates of BHP and the Company.
The EPA issued a NOV on May 19, 1998, against Tesoro Alaska Petroleum
Company, a subsidiary of the Company, alleging violations of the Resource
Conservation and Recovery Act ("RCRA") associated with the failure to
maintain closure of certain containers of hazardous waste at the Alaska
Refinery when not in use and the failure to retain on-site certain records
of land disposal restriction notifications. The Company has initiated an
investigation into these allegations, but does not believe that the
resolution thereof will have a material effect on the Company.
The EPA has notified Shell Washington that it is a PRP at the Swinomish
dump site in Washington State. In the environmental agreement between
Shell Washington and the Company, the Shell Seller has fully indemnified
the Company for environmental liabilities arising from wastes delivered to
the Swinomish dump site prior to the closing of the Washington Acquisition.
26
<PAGE>
ITEM 2. CHANGES IN SECURITIES AND USE OF PROCEEDS
On July 2, 1998, the Company entered into the Senior Credit Facility under
which the Company is required to maintain specified levels of consolidated
leverage and interest coverage and contains other covenants and
restrictions customary in credit arrangements of this kind. Among other
matters, the terms of the Senior Credit Facility allow for payment of cash
dividends on its Common Stock not to exceed an aggregate of $10 million in
any year and also allow for payment of required dividends on its 7.25%
Mandatorily Convertible Preferred Stock.
Concurrently with the syndication of the Senior Credit Facility, on July 2,
1998, the Company issued the Senior Subordinated Notes. The Indenture
governing the Senior Subordinated Notes contains customary covenants and
restrictions which are less restrictive than those under the Senior Credit
Facility. To the extent the Company's fixed charge coverage ratio, as
defined in the Indenture, allows for the incurrence of additional
indebtedness, the Company will be allowed to pay cash dividends on Common
Stock.
For further information related to the Senior Credit Facility and Senior
Subordinated Notes, see Note C of Notes to Condensed Consolidated Financial
Statements in Part I, Item 1.
On July 1, 1998 the Company issued 9,000,000 PIES and on July 8, 1998 the
Company issued 1,350,000 PIES. Each PIES consists of a depositary share
representing one one-hundredth of a share of 7.25% Mandatorily Convertible
Preferred Stock ("Mandatorily Convertible Preferred Stock") of the Company.
Dividends are payable at $1.1555 per annum per PIES, subject to upward
adjustment in certain events. At any time after July 26, 1998 but before
July 1, 2001 (the "Mandatory Conversion Date"), each PIES is convertible,
at the option of the holder thereof, into 0.8455 shares of Common Stock,
subject to adjustment in certain events. On the Mandatory Conversion Date,
each PIES not previously converted will automatically convert into shares
of Common Stock at the Conversion Rate. The "Conversion Rate" is, subject
to adjustment in certain events, equal to (a) if the Conversion Price (as
defined below) is greater than or equal to $18.85 (the "Threshold
Appreciation Price"), 0.8455 shares of Common Stock per PIES, (b) if the
Conversion Price is less than $18.85 but more than $15.9375 (the "Initial
Price"), a fraction, equal to the Initial Price divided by the Conversion
Price, of one share of Common Stock per PIES and (c) if the Conversion
Price is less than or equal to the Initial Price, one share of Common Stock
per PIES. The Threshold Appreciation Price and the Initial Price are also
subject to adjustment in certain events. The "Conversion Price" is the
average closing price per share of Common Stock for the 20 trading days
immediately prior to, but not including, the Mandatory Conversion Date.
The holders of PIES are entitled to direct the voting of the shares of
Mandatorily Convertible Preferred Stock. The Mandatorily Convertible
Preferred Stock has no voting rights, except as required by applicable
state law and except that (i) if dividends on the Mandatorily Convertible
Preferred Stock or any other series of the Company's Preferred Stock are in
arrears and unpaid for six consecutive quarterly dividend periods, or if
any other series of the Company's Preferred Stock shall be entitled for any
other reason to exercise voting rights, separate from the Common Stock, to
elect any directors of the Company, the Mandatorily Convertible Preferred
Stock (voting as a class with certain other series of Preferred Stock) will
be entitled to elect two directors of the Company and (ii) the Mandatorily
Convertible Preferred Stock has voting rights with respect to certain
alterations of the Company's Restated Certificate of Incorporation and
Bylaws and the creation or authorization of Preferred Stock or other
capital stock (or securities convertible into capital stock) ranking prior
to the Mandatorily Convertible Preferred Stock as to the payment of
dividends or liquidation preferences. The Mandatorily Convertible
Preferred Stock ranks prior to the Common Stock as to payment of dividends
and distributions of assets upon liquidation. The liquidation preference
of each PIES is an amount equal to the sum of (i) $15.9375 and (ii) all
accrued and unpaid dividends thereon.
27
<PAGE>
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
See the Exhibit Index immediately preceding the exhibits filed
herewith.
(b) Reports on Form 8-K
A Current Report on Form 8-K was filed on May 13, 1998, reporting
information under Item 5 related to the Company's acquisition of all of
the outstanding stock of BHP Petroleum Americas Refining Inc. and BHP
Petroleum South Pacific Inc. (collectively, "BHP Hawaii") and filing
financial statements of BHP Hawaii and related pro forma financial
information under Item 7. Financial statements included in the Form
8-K were as follows: (i) Audited Combined Financial Statements of BHP
Petroleum Americas Refining Inc. and BHP Petroleum South Pacific Inc.
as of May 31, 1997 and 1996; and (ii) Unaudited Combined Financial
Statements of BHP Petroleum Americas Refining Inc. and BHP Petroleum
South Pacific Inc. as of December 31, 1997 and 1996. Pro Forma
Combined Condensed Financial Statements of the Company, BHP Petroleum
Americas Refining Inc. and BHP Petroleum South Pacific Inc. as of and
for the year ended December 31, 1997 were also filed.
A Current Report on Form 8-K, dated May 29, 1998, was filed on June 5,
1998, reporting under Item 2, Acquisition or Disposition of Assets,
that on May 29, 1998 the Company completed the acquisition of all of
the outstanding capital stock of BHP Petroleum Americas Refining Inc.
and BHP Petroleum South Pacific Inc., both of which were affiliates of
The Broken Hill Proprietary Company Limited. Combined financial
statements of BHP Petroleum Americas Refining Inc. and BHP Petroleum
South Pacific Inc. and related pro forma financial information had been
previously filed in the Current Report on Form 8-K filed on May 13,
1998. Included under Item 7 of the Form 8-K dated May 29, 1998 and
filed on June 5, 1998 were the following: (i) Audited Financial
Statements of Shell Anacortes Refining Company as of December 31, 1996
and 1997 and (ii) Unaudited Financial Statements of Shell Anacortes
Refining Company as of March 31, 1998.
A Current Report on Form 8-K, dated June 25, 1998 was filed on July 1,
1998, reporting under Item 5, Other Events, that the Company had issued
9,000,000 Premium Income Equity Securities and 5,000,000 shares of
Common Stock. Exhibits were also filed under Item 7.
28
<PAGE>
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
TESORO PETROLEUM CORPORATION
REGISTRANT
Date: August 14, 1998 /s/ BRUCE A. SMITH
Bruce A. Smith
Chairman of the Board of Directors,
President and Chief Executive Officer
Date: August 14, 1998 /s/ DON M. HEEP
Don M. Heep
Vice President, Controller
(Chief Accounting Officer)
29
<PAGE>
EXHIBIT INDEX
EXHIBIT
NUMBER
27 Financial Data Schedule (June 30, 1998).
30
<PAGE>
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM TESORO
PETROLEUM CORPORATION'S FINANCIAL STATEMENTS AS OF AND FOR THE SIX MONTH PERIOD
ENDED JUNE 30, 1998 AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH
FINANCIAL STATEMENTS.
</LEGEND>
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 6-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-END> JUN-30-1998
<CASH> 26,408
<SECURITIES> 0
<RECEIVABLES> 113,939
<ALLOWANCES> 1,886
<INVENTORY> 175,446
<CURRENT-ASSETS> 322,860
<PP&E> 997,918
<DEPRECIATION> 331,730
<TOTAL-ASSETS> 1,041,888
<CURRENT-LIABILITIES> 160,670
<BONDS> 451,670
<COMMON> 4,480
0
0
<OTHER-SE> 345,957
<TOTAL-LIABILITY-AND-EQUITY> 1,041,888
<SALES> 453,450
<TOTAL-REVENUES> 474,868
<CGS> 378,333
<TOTAL-COSTS> 378,333
<OTHER-EXPENSES> 28,155
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 8,418
<INCOME-PRETAX> 29,929
<INCOME-TAX> 12,993
<INCOME-CONTINUING> 16,936
<DISCONTINUED> 0
<EXTRAORDINARY> (4,641)
<CHANGES> 0
<NET-INCOME> 12,295
<EPS-PRIMARY> 0.47 <F1>
<EPS-DILUTED> 0.46 <F1>
<FN>
<F1> Earnings per share is after an extraordinary loss of $4.6 million ($0.17 loss per basic
and diluted share) on extinguishment of debt.
</TABLE>
