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 SEPTEMBER 30, 1999
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 32,410,975 shares of the registrant's Common Stock outstanding at
October 31, 1999.
<PAGE>
TESORO PETROLEUM CORPORATION AND SUBSIDIARIES
QUARTERLY REPORT ON FORM 10-Q
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 1999
TABLE OF CONTENTS
PAGE
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements (Unaudited)
Condensed Consolidated Balance Sheets - September 30, 1999
and December 31, 1998 . . . . . . . . . . . . . . . . . . . . 3
Condensed Statements of Consolidated Operations - Three Months
and Nine Months Ended September 30, 1999 and 1998. . . . . . . 4
Condensed Statements of Consolidated Cash Flows - Nine Months
Ended September 30, 1999 and 1998. . . . . . . . . . . . . . . 5
Notes to Condensed Consolidated Financial Statements. . . . . . 6
Item 2. Management's Discussion and Analysis of Financial
Condition and Results of Operations . . . . . . . . . . . . . . 14
Item 3. Quantitative and Qualitative Disclosures About Market
Risk. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28
PART II. OTHER INFORMATION
Item 1. Legal Proceedings . . . . . . . . . . . . . . . . . . . 30
Item 4. Submission of Matters to a Vote of Security Holders . . 30
Item 6. Exhibits and Reports on Form 8-K. . . . . . . . . . . . 31
SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32
EXHIBIT INDEX. . . . . . . . . . . . . . . . . . . . . . . . . . . 33
2
<PAGE>
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
TESORO PETROLEUM CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(UNAUDITED)
(DOLLARS IN MILLIONS EXCEPT PER SHARE AMOUNTS)
September 30, December 31,
1999 1998
---- ----
ASSETS
<S> <C> <C>
CURRENT ASSETS
Cash and cash equivalents . . . . . . . . . . . . . . . . . . . . . $ 15.6 $ 12.9
Receivables, less allowance for doubtful accounts . . . . . . . . . 244.6 157.5
Inventories . . . . . . . . . . . . . . . . . . . . . . . . . . . . 197.7 208.2
Prepayments and other . . . . . . . . . . . . . . . . . . . . . . . 10.6 12.0
--------- ---------
Total Current Assets . . . . . . . . . . . . . . . . . . . . . . . 468.5 390.6
--------- ---------
PROPERTY, PLANT AND EQUIPMENT
Refining and marketing. . . . . . . . . . . . . . . . . . . . . . . 878.3 841.0
Marine services . . . . . . . . . . . . . . . . . . . . . . . . . . 53.2 50.8
Exploration and production, full-cost method of accounting. . . . . 474.4 426.5
Corporate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29.0 21.4
--------- ---------
1,434.9 1,339.7
Less accumulated depreciation, depletion and amortization . . . . . 496.6 445.1
--------- ---------
Net Property, Plant and Equipment. . . . . . . . . . . . . . . . . 938.3 894.6
--------- ---------
OTHER ASSETS . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150.5 143.2
--------- ---------
Total Assets. . . . . . . . . . . . . . . . . . . . . . . . . . . $ 1,557.3 $ 1,428.4
========= =========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts payable. . . . . . . . . . . . . . . . . . . . . . . . . . $ 183.7 $ 126.4
Accrued liabilities . . . . . . . . . . . . . . . . . . . . . . . . 97.9 69.3
Current maturities of long-term debt and other obligations. . . . . 24.5 12.5
--------- ---------
Total Current Liabilities. . . . . . . . . . . . . . . . . . . . . 306.1 208.2
--------- ---------
DEFERRED INCOME TAXES. . . . . . . . . . . . . . . . . . . . . . . . 82.7 69.9
--------- ---------
OTHER LIABILITIES . . . . . . . . . . . . . . . . . . . . . . . . . 68.3 59.7
--------- ---------
LONG-TERM DEBT AND OTHER OBLIGATIONS, LESS CURRENT
MATURITIES . . . . . . . . . . . . . . . . . . . . . . . . . . . . 491.0 531.4
--------- ---------
COMMITMENTS AND CONTINGENCIES (Note F)
STOCKHOLDERS' EQUITY
Preferred stock, no par value; authorized 5,000,000 shares:
7.25% Mandatorily Convertible Preferred Stock, 103,500 shares
issued and outstanding . . . . . . . . . . . . . . . . . . . . . . 165.0 165.0
Common stock, par value $0.16-2/3; authorized 100,000,000 shares;
32,703,856 shares issued (32,654,138 in 1998). . . . . . . . . . . 5.4 5.4
Additional paid-in capital. . . . . . . . . . . . . . . . . . . . . 279.1 278.6
Retained earnings . . . . . . . . . . . . . . . . . . . . . . . . . 164.7 115.6
Treasury stock, 296,045 common shares (320,022 in 1998), at cost. . (5.0) (5.4)
--------- ---------
Total Stockholders' Equity . . . . . . . . . . . . . . . . . . . . 609.2 559.2
--------- ---------
Total Liabilities and Stockholders' Equity. . . . . . . . . . . . $ 1,557.3 $ 1,428.4
========= =========
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 MILLIONS EXCEPT PER SHARE AMOUNTS)
Three Months Ended Nine Months Ended
September 30, September 30,
------------------- -------------------
1999 1998 1999 1998
---- ---- ---- ----
<S> <C> <C> <C> <C>
REVENUES
Refining and marketing. . . . . . . . . . . . . $ 838.0 $ 424.7 $ 2,021.3 $ 772.5
Marine services . . . . . . . . . . . . . . . . 55.5 28.5 104.4 90.4
Exploration and production. . . . . . . . . . . 18.7 19.3 49.0 63.1
Other income. . . . . . . . . . . . . . . . . . 0.8 0.2 1.0 21.6
--------- --------- --------- ---------
Total Revenues . . . . . . . . . . . . . . . . 913.0 472.7 2,175.7 947.6
--------- --------- --------- ---------
OPERATING COSTS AND EXPENSES
Refining and marketing. . . . . . . . . . . . . 773.1 397.6 1,852.5 711.1
Marine services . . . . . . . . . . . . . . . . 50.7 24.8 97.6 82.3
Exploration and production. . . . . . . . . . . 4.4 3.8 13.8 11.2
Depreciation, depletion and amortization. . . . 17.3 17.9 50.7 45.7
--------- --------- --------- ---------
Total Segment Operating Costs and Expenses . . 845.5 444.1 2,014.6 850.3
--------- --------- --------- ---------
SEGMENT OPERATING PROFIT . . . . . . . . . . . . 67.5 28.6 161.1 97.3
General and administrative expenses. . . . . . . (8.0) (4.5) (23.3) (11.7)
Interest and financing costs . . . . . . . . . . (12.0) (10.9) (36.5) (20.7)
Interest income. . . . . . . . . . . . . . . . . 0.3 1.5 0.7 1.9
Other expense, including other operating costs . (4.3) (0.8) (6.6) (23.0)
--------- --------- --------- ---------
EARNINGS BEFORE INCOME TAXES AND
EXTRAORDINARY ITEM. . . . . . . . . . . . . . . 43.5 13.9 95.4 43.8
Income tax provision . . . . . . . . . . . . . . 18.2 6.1 37.3 19.1
--------- --------- --------- ---------
EARNINGS BEFORE EXTRAORDINARY ITEM . . . . . . . 25.3 7.8 58.1 24.7
Extraordinary loss on extinguishment of debt,
net of income tax benefit of $2.4 in 1998 . . . - - - (4.6)
--------- --------- --------- ---------
NET EARNINGS . . . . . . . . . . . . . . . . . . 25.3 7.8 58.1 20.1
Preferred dividend requirements. . . . . . . . . 3.0 3.0 9.0 3.0
--------- --------- --------- ---------
NET EARNINGS APPLICABLE TO COMMON STOCK. . . . . $ 22.3 $ 4.8 $ 49.1 $ 17.1
========= ========= ========= =========
NET EARNINGS PER SHARE - BASIC . . . . . . . . . $ 0.69 $ 0.15 $ 1.52 $ 0.60
========= ========= ========= =========
NET EARNINGS PER SHARE - DILUTED . . . . . . . . $ 0.58 $ 0.15 $ 1.35 $ 0.59
========= ========= ========= =========
WEIGHTED AVERAGE COMMON SHARES - BASIC . . . . . 32.4 32.3 32.4 28.4
========= ========= ========= =========
WEIGHTED AVERAGE COMMON AND POTENTIALLY
DILUTIVE COMMON SHARES - DILUTED. . . . . . . . 43.3 32.9 43.1 29.0
========= ========= ========= =========
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 MILLIONS)
Nine Months Ended
September 30,
-------------------
1999 1998
---- -----
<S> <C> <C>
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES
Net earnings. . . . . . . . . . . . . . . . . . . . . $ 58.1 $ 20.1
Adjustments to reconcile net earnings to net cash
from operating activities:
Depreciation, depletion and amortization. . . . . . 52.2 46.3
Extraordinary loss on extinguishment of debt,
net of income tax benefit. . . . . . . . . . . . . - 4.6
Amortization of deferred charges and other. . . . . 6.5 10.1
Changes in operating assets and liabilities:
Receivables. . . . . . . . . . . . . . . . . . . . (86.5) (40.7)
Inventories. . . . . . . . . . . . . . . . . . . . 10.5 (12.1)
Accounts payable and accrued liabilities . . . . . 82.1 70.4
Deferred income taxes. . . . . . . . . . . . . . . 13.8 3.2
Other assets and liabilities . . . . . . . . . . . 10.9 (3.2)
------- -------
Net cash from operating activities . . . . . . . 147.6 98.7
------- -------
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES
Capital expenditures. . . . . . . . . . . . . . . . . (99.7) (131.3)
Acquisitions and other. . . . . . . . . . . . . . . . 0.1 (528.1)
------- -------
Net cash used in investing activities. . . . . . (99.6) (659.4)
------- -------
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Repayments under revolving credit and interim
facilities, net of borrowings. . . . . . . . . . . . (61.2) (24.1)
Repayments of other debt and obligations. . . . . . . (25.5) (92.2)
Issuance of other long-term debt. . . . . . . . . . . 50.0 150.0
Payments of dividends on preferred stock. . . . . . . (9.0) -
Proceeds from equity and debt offerings, net. . . . . - 532.8
Financing costs and other . . . . . . . . . . . . . . 0.4 (10.7)
------- -------
Net cash from (used in) financing activities . . (45.3) 555.8
------- -------
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS. . . . 2.7 (4.9)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD. . . . . 12.9 8.4
------- -------
CASH AND CASH EQUIVALENTS, END OF PERIOD. . . . . . . . $ 15.6 $ 3.5
======= =======
SUPPLEMENTAL CASH FLOW DISCLOSURES
Interest paid, net of capitalized interest of
$0.3 in 1999 and $0.1 in 1998. . . . . . . . . . . . $ 40.8 $ 9.8
======= =======
Income taxes paid . . . . . . . . . . . . . . . . . . $ 33.7 $ 13.5
======= =======
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)
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.
The balance sheet at December 31, 1998 has been condensed from the audited
consolidated financial statements at that date. 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, 1998.
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.
Certain reclassifications have been made to information previously reported to
conform to current presentations.
NOTE B - INVENTORIES
Components of inventories were as follows (in millions):
<TABLE>
<CAPTION>
September 30, December 31,
1999 1998
---- ----
<S> <C> <C>
Crude oil and wholesale refined products, at LIFO . . $ 166.0 $ 182.4
Merchandise and other refined products. . . . . . . . 12.7 10.5
Materials and supplies. . . . . . . . . . . . . . . . 19.0 15.3
------ ------
Total inventories . . . . . . . . . . . . . . . . . $ 197.7 $ 208.2
====== ======
</TABLE>
NOTE C - DIVESTMENTS, ACQUISITIONS AND CAPITAL PROJECTS
EXPLORATION AND PRODUCTION
In May 1999, the Company announced that its Board of Directors had approved
seeking alternative value-creating opportunities, including a spin-off, trade,
sale and other options, for its Exploration and Production segment. Both the
Refining and Marketing and Exploration and Production segments have growth
opportunities which require additional investment. Given the Company's
strategic objectives and its desire to improve financial flexibility, management
believes that it would not be able to prudently fund all these opportunities.
In this regard, in October 1999, the Company entered into a definitive agreement
to sell substantially all of its domestic exploration and production business to
EEX Corporation at a cash sales price of $216 million. Under the terms of the
agreement, the transaction will be structured as a stock sale. This
transaction, which is subject to certain closing conditions, is expected to
occur on or about November 30, 1999. The sales price will be adjusted for
transaction costs and certain purchase price adjustments for business activity
that occurs between July 1, 1999 and closing. Net after-tax cash proceeds are
estimated to be $170 million. The total impact of the domestic exploration and
production divestment is expected to contribute approximately $0.60 per share to
the Company's earnings on an after-tax diluted basis during the last half of
1999. This includes approximately $0.45 per diluted share for a gain from the
sale expected in the 1999 fourth quarter and $0.08 and $0.07 per diluted share
for domestic exploration and production operations during the 1999 third and
fourth quarters, respectively. Proceeds from this sale are expected to be used
to reduce Tesoro's term loans under its senior credit facility ("Credit
Facility"), which would decrease the Company's debt-to-capitalization ratio to
approximately 35%.
6
<PAGE>
The Company is continuing to evaluate value-creating opportunities for its
exploration and production operations in Bolivia.
REFINING AND MARKETING AND MARINE SERVICES
In August 1999, the Company purchased a refined products terminal in Anchorage,
Alaska, for approximately $8 million in cash. This terminal, which is near the
Company's existing terminal in Anchorage, will provide the Company with
additional storage and purchasing flexibility.
In June 1999, the Company purchased the U.S. West Coast marine fuels operations
of BP Marine, a division of BP Amoco PLC. The purchase, which included
inventory and leased facilities at Port Angeles and Seattle, Washington, and
Portland, Oregon, expanded the Marine Services segment's presence on the West
Coast.
In addition to normal capital improvements in 1999, the Company is in the
process of installing a distillate treater at its Washington refinery which will
enable the refinery to increase its production of low-sulfur diesel fuel and jet
fuel. Management estimates that the distillate treater installation, together
with licensing fees and supporting infrastructure, will cost approximately $13
million and will be completed by year-end 1999. The Company has spent
approximately $5 million for the installation through September 30, 1999.
NOTE D - LONG-TERM DEBT
On October 1, 1999, the Company and its lenders amended the Credit Facility,
which is comprised of term loans ("Term Loans") and a revolving credit and
letter of credit facility ("Revolver"), to permit the Company to sell its
Exploration and Production segment, as discussed in Note C, in one or more
transactions. The amendment requires the Company to use the proceeds from the
sale of the Exploration and Production segment to reduce the Term Loans
outstanding under the Credit Facility. At September 30, 1999, the Company had
$178.6 million outstanding under the Term Loans and no outstanding borrowings
under the Revolver.
In April 1999, the Company elected to reduce availability under the Revolver
from $300 million to $175 million, reducing commitment fees. Based on current
needs, the remaining credit capacity is expected to be sufficient to fund
capital expenditures and working capital requirements.
NOTE E - OPERATING SEGMENTS
The Company's revenues are derived from three operating segments: Refining and
Marketing, Marine Services and Exploration and Production. Management has
identified these segments for managing operations and investing activities. The
segments are organized primarily by petroleum industry classification as
upstream (Exploration and Production) and downstream (Refining and Marketing,
and Marine Services). These classifications represent significantly different
activities with respect to investment, asset development, asset valuations,
production, maintenance, supply and market distribution. The downstream
businesses are organized into two segments representing (i) marketing of
manufactured and purchased refined products and (ii) the product distribution
and logistics services provided to the marine industry. See Note C for
information on an agreement to sell substantially all of the Company's domestic
exploration and production business and evaluation of value-creating
opportunities for its Bolivian operations.
Segment operating profit includes those revenues and expenses that are directly
attributable to management of the respective segment. For the periods
presented, revenues were generated from sales to external customers, and
intersegment revenues were not significant. Income taxes, interest and
financing costs, interest income and corporate general and administrative
expenses are not included in determining segment operating profit.
7
<PAGE>
EBITDA represents earnings before extraordinary items, interest and financing
costs, income taxes and depreciation, depletion and amortization. While not
purporting to reflect any measure of the Company's operations or cash flows,
EBITDA is presented for additional analysis. Operating segment EBITDA is equal
to segment operating profit before depreciation, depletion and amortization
related to each segment.
Identifiable assets are those assets utilized by the segment. Corporate assets
are principally cash, property and other assets that are not directly associated
with the operations of an operating segment. Segment information is as follows
(in millions):
8
<PAGE>
<TABLE>
<CAPTION>
Three Months Ended Nine Months Ended
September 30, September 30,
------------------- --------------------
1999 1998 1999 1998
---- ---- ---- ----
<S> <C> <C> <C> C>
REVENUES
Gross operating revenues:
Refining and Marketing. . . . . . . . . . . . . . . . . $ 838.0 $ 424.7 $ 2,021.3 $ 772.5
Marine Services . . . . . . . . . . . . . . . . . . . . 55.5 28.5 104.4 90.4
Exploration and Production -
U.S. <F1>. . . . . . . . . . . . . . . . . . . . . . . 15.8 16.5 43.5 54.3
Latin America. . . . . . . . . . . . . . . . . . . . . 2.9 2.8 5.5 8.8
-------- -------- -------- --------
Total Gross Operating Revenues . . . . . . . . . . . . 912.2 472.5 2,174.7 926.0
Other income <F1>. . . . . . . . . . . . . . . . . . . . 0.8 0.2 1.0 21.6
-------- -------- -------- --------
Total Revenues . . . . . . . . . . . . . . . . . . . $ 913.0 $ 472.7 $ 2,175.7 $ 947.6
======== ======== ======== ========
SEGMENT OPERATING PROFIT
Refining and Marketing . . . . . . . . . . . . . . . . . $ 55.6 $ 19.1 $ 141.7 $ 45.6
Marine Services. . . . . . . . . . . . . . . . . . . . . 4.2 3.1 4.8 6.5
Exploration and Production -
U.S. <F1> . . . . . . . . . . . . . . . . . . . . . . . 6.0 5.3 13.4 41.7
Latin America . . . . . . . . . . . . . . . . . . . . . 1.7 1.1 1.2 3.5
-------- -------- -------- --------
Total Segment Operating Profit . . . . . . . . . . . . 67.5 28.6 161.1 97.3
Corporate and Unallocated Costs <F2> . . . . . . . . . . (24.0) (14.7) (65.7) (53.5)
-------- -------- -------- --------
Earnings Before Income Taxes and Extraordinary Item. . . $ 43.5 $ 13.9 $ 95.4 $ 43.8
======== ======== ======== ========
EBITDA
Refining and Marketing . . . . . . . . . . . . . . . . . $ 65.1 $ 27.0 $ 169.0 $ 60.8
Marine Services. . . . . . . . . . . . . . . . . . . . . 4.8 3.8 6.8 8.3
Exploration and Production -
U.S. <F1> . . . . . . . . . . . . . . . . . . . . . . . 12.5 13.8 33.3 68.4
Latin America . . . . . . . . . . . . . . . . . . . . . 2.4 1.9 2.7 5.5
-------- -------- -------- --------
Total Operating Segment EBITDA . . . . . . . . . . . . 84.8 46.5 211.8 143.0
Corporate and Unallocated <F2> . . . . . . . . . . . . . (11.4) (3.6) (27.7) (32.2)
-------- -------- -------- --------
Total Consolidated EBITDA. . . . . . . . . . . . . . . 73.4 42.9 184.1 110.8
Depreciation, Depletion and Amortization . . . . . . . . (17.9) (18.1) (52.2) (46.3)
Interest and Financing Costs . . . . . . . . . . . . . . (12.0) (10.9) (36.5) (20.7)
-------- -------- -------- --------
Earnings Before Income Taxes and Extraordinary Item. . . $ 43.5 $ 13.9 $ 95.4 $ 43.8
======== ======== ======== ========
DEPRECIATION, DEPLETION AND AMORTIZATION
Refining and Marketing . . . . . . . . . . . . . . . . . $ 9.5 $ 7.9 $ 27.3 $ 15.2
Marine Services. . . . . . . . . . . . . . . . . . . . . 0.6 0.7 2.0 1.8
Exploration and Production -
U.S. <F1> . . . . . . . . . . . . . . . . . . . . . . . 6.5 8.5 19.9 26.7
Latin America . . . . . . . . . . . . . . . . . . . . . 0.7 0.8 1.5 2.0
Corporate. . . . . . . . . . . . . . . . . . . . . . . . 0.6 0.2 1.5 0.6
-------- -------- -------- --------
Total Depreciation, Depletion and Amortization. . . . . $ 17.9 $ 18.1 $ 52.2 $ 46.3
======== ======== ======== ========
CAPITAL EXPENDITURES
Refining and Marketing . . . . . . . . . . . . . . . . . $ 24.1 $ 13.7 $ 43.1 $ 20.9
Marine Services. . . . . . . . . . . . . . . . . . . . . 0.4 0.4 2.2 3.0
Exploration and Production -
U.S. <F1> . . . . . . . . . . . . . . . . . . . . . . . 8.4 38.0 33.1 76.5
Latin America . . . . . . . . . . . . . . . . . . . . . 2.2 15.2 14.9 26.7
Corporate. . . . . . . . . . . . . . . . . . . . . . . . 2.1 1.7 6.4 4.2
-------- -------- -------- --------
Total Capital Expenditures. . . . . . . . . . . . . . . $ 37.2 $ 69.0 $ 99.7 $ 131.3
======== ======== ======== ========
9
<PAGE>
September 30, December 31,
1999 1998
---- ----
IDENTIFIABLE ASSETS
Refining and Marketing . . . . . . . . . . . . . . . . . $ 1,150.1 $ 1,077.7
Marine Services. . . . . . . . . . . . . . . . . . . . . 82.8 59.2
Exploration and Production -
U.S.. . . . . . . . . . . . . . . . . . . . . . . . . . 185.7 175.8
Latin America . . . . . . . . . . . . . . . . . . . . . 67.4 58.9
Corporate. . . . . . . . . . . . . . . . . . . . . . . . 71.3 56.8
-------- --------
Total Assets . . . . . . . . . . . . . . . . . . . . . $ 1,557.3 $ 1,428.4
======== ========
<FN>
<F1> Subsequent to September 30, 1999, the Company has entered into an agreement to sell substantially all of its domestic
exploration and production business. This transaction, which is subject to certain closing conditions, is expected to
occur on or about November 30, 1999. Operating profit for the nine months ended September 30, 1998 included
income from receipt of $21.3 million from an operator in the Bob West Field, representing funds no longer needed as
a contingency reserve for litigation.
<F2> Corporate and unallocated costs for the nine months ended September 30, 1998 included $19.9 million (of which
$7.9 million related to the operating segments) for special incentive compensation which was earned when the market
price of the Company's common stock achieved a certain performance target in May 1998.
</TABLE>
NOTE F - COMMITMENTS AND CONTINGENCIES
The Company is a party to various litigation and contingent loss situations,
including environmental matters, arising in the ordinary course of business.
The Company has made accruals in accordance with Statement of Financial
Accounting Standard No. 5, "Accounting for Contingencies," in order to provide
for such matters. The ultimate effects of these matters cannot be predicted
with certainty, and related accruals are based on management's best estimates,
subject to future developments. Although the resolution of certain of these
matters could have a material adverse impact on interim or annual results of
operations, the Company believes that the outcome of these matters will not
result in a material adverse effect on its liquidity or consolidated financial
position.
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 the Environmental Protection Agency
("EPA") regarding a waste disposal site near Abbeville, Louisiana and the
Casmalia Disposal Site in Santa Barbara County, California. The Company has
been named a potentially responsible party ("PRP") under the Federal
Comprehensive Environmental Response, Compensation and Liability Act ("CERCLA"
or "Superfund") at both sites. Although the Superfund law might impose joint
and several liability upon each party at the sites, the extent of the Company's
allocated financial contributions for cleanup is expected to be de minimis based
upon the number of companies, volumes of waste involved and total estimated
costs to close each site. The Company believes, based on these considerations
and discussions with the EPA, that its liability at the Abbeville site will not
exceed $25,000. The Company believes that its liability at the Casmalia Site,
based on an October 1999 notification from the EPA, will not exceed $80,000.
In connection with the 1998 acquisition of the Hawaii refining and marketing
operations from affiliates of The Broken Hill Proprietary Company Limited ("BHP
Sellers"), the BHP Sellers and the Company executed a separate environmental
agreement, whereby the BHP Sellers 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
10
<PAGE>
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 1998 acquisition of the Washington refinery
from an affiliate of Shell Oil Company ("Shell Seller"), the Shell Seller
generally 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
equally between the Company and the Shell Seller, subject to an aggregate
maximum of $5.0 million and a ten-year term.
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 own properties. At September 30, 1999, the Company's
accruals for environmental expenses amounted to $12.2 million. Based on
currently available information, including the participation of other parties or
former owners in remediation actions, the Company believes these accruals are
adequate.
To comply with existing environmental laws and regulations, the Company
anticipates that it will make capital improvements totaling approximately $8
million in 1999 and $5 million in 2000. In addition, capital expenditures for
alternative secondary containment systems for existing storage tank facilities
are estimated to be $1 million in 1999 and $2 million in 2000, with a remaining
$3 million expected to be spent by 2002.
The Company is currently evaluating certain proposed revisions to the Clean Air
Act regulations which would require a reduction in the sulfur content in
gasoline fuel manufactured at its refineries. Although the proposed revisions
are not finalized, the Company expects that it will make capital improvements to
certain equipment at its Washington refinery to meet the expected gasoline
standard. Additional proposed changes to the Clean Air Act regulations may
include new emission controls at certain processing units at each of the
Company's refineries. The Company anticipates that the revisions to the Clean
Air Act will become effective over the next three to five years and that, based
on known current technology, it could spend approximately $25 million to $30
million to comply with these proposed revisions.
Conditions that require additional expenditures may exist for various Company
sites, including, but not limited to, the Company's refineries, retail gasoline
stations (operating and closed locations) and petroleum product terminals, and
for compliance with the Clean Air Act and other state and federal regulations.
The amount of such future expenditures cannot currently be determined by the
Company.
For further information regarding environmental matters, see Legal Proceedings
in Part II, Item 1, included herein.
LITIGATION
On October 1, 1998, the Attorney General for the State of Hawaii filed a lawsuit
in the U.S. District Court for the District of Hawaii against thirteen oil
companies, including Tesoro Petroleum Corporation and Tesoro Hawaii Corporation,
alleging anti-competitive marketing practices in violation of federal and state
anti-trust laws, and seeking injunctive relief and compensatory and treble
damages and civil penalties against all defendants in an amount in excess of
$500 million. On March 25, 1999, the Attorney General filed an amended
complaint with the U.S. District Court seeking damages against all defendants
for such alleged anti-competitive marketing practices in an amount in excess of
$1.3 billion. The Company believes that it has not engaged in any
anti-competitive activities and intends to defend this litigation accordingly.
This proceeding is subject to the indemnity provision of the stock sale
agreement between the BHP Sellers and the Company which provides for
indemnification in excess of $2 million and not to exceed $65 million.
11
<PAGE>
OTHER
In October 1998, the Company's Board of Directors unanimously approved the 1998
Performance Incentive Compensation Plan ("Performance Plan"), which is intended
to advance the best interests of the Company and its stockholders by directly
targeting Company performance to align with the ninetieth percentile historical
stock-price growth rate for the Company's peer group. In addition, the
Performance Plan will provide the Company's employees with additional
compensation, contingent upon achievement of the targeted objectives, thereby
encouraging them to continue in the employ of the Company. Under the
Performance Plan, targeted objectives are comprised of the fair market value of
the Company's Common Stock equaling or exceeding an average of $35 per share
("First Performance Target") and $45 per share ("Second Performance Target") on
any 20 consecutive trading days during a period commencing on October 1, 1998
and ending on the earlier of September 30, 2002, or the date on which the Second
Performance Target is achieved ("Performance Period"). The Performance Plan has
several tiers of awards, with the award generally determined by job level. Most
eligible employees have contingent cash bonus opportunities of 25% of their
annual "basic compensation" (as defined in the Performance Plan) and three
executive officers have contingent awards totaling 655,000 shares of phantom
stock which will be payable solely in cash. Upon achievement of the First
Performance Target, one-fourth of the contingent award will be earned, with
payout deferred until the end of the Performance Period. The remaining 75% will
be earned only upon achievement of the Second Performance Target, with payout
occurring 30 days thereafter. Employees will need to have at least one year of
regular, full-time service at the time the Performance Period ends in order to
be eligible for a payment. No costs will be recorded until the First
Performance Target is reached. The Company estimates that it will incur costs
of approximately 2% of the total aggregate increase in shareholder value if the
First Performance Target is reached and will incur an additional 4% charge if
the Second Performance Target is reached.
In the 1999 third quarter, the Company entered into a charter for a double-hull
tanker to be used for transporting crude oil and refined products. Under the
terms of the new charter, Tesoro will receive one of the new Lightship Class
tankers that entered service in October 1998. The new charter, which has a
three-year primary term beginning in May 2000 and two one-year options, will
require future minimum annual lease payments of approximately $10 million. The
new charter will save the Company approximately $5 million to $6 million
annually when it replaces the Chesapeake Trader, which goes off charter to
Tesoro in May 2000. Tesoro has another ship under charter, the Potomac Trader,
which goes off charter to Tesoro in September 2000. Management is continuing to
evaluate the Company's requirements for chartered vessels and believes that,
based on current market conditions, shipping costs could be further reduced in
2000 and 2001.
12
<PAGE>
NOTE G - EARNINGS PER SHARE
Basic earnings per share is determined by dividing net earnings applicable to
common stock by the weighted average number of common shares outstanding during
the period. The calculation of diluted earnings per share takes into account
the effect of potentially dilutive shares, principally stock options outstanding
during the period, and the maximum shares which would have been issued assuming
conversion of preferred stock at the beginning of the period. The preferred
stock is represented by Premium Income Equity Securities ("PIES") which will
convert automatically into shares of common stock on July 1, 2001, at conversion
rates ranging from 0.8455 shares to 1.0 share of common stock for each PIES,
depending upon the market price of the common stock. Before July 1, 2001, each
PIES is convertible at the option of the holder thereof into 0.8455 shares of
common stock. The maximum conversion rate of 1.0 common share for each PIES is
used in the 1999 earnings per share calculations. Earnings per share
calculations are presented below (in millions except per share amounts):
<TABLE>
<CAPTION>
Three Months Ended Nine Months Ended
September 30, September 30,
------------------ -----------------
1999 1998 1999 1998
---- ---- ---- ----
<S> <C> <C> <C> <C>
BASIC:
Numerator:
Earnings before extraordinary item . . . . . . . . . . . $ 25.3 $ 7.8 $ 58.1 $ 24.7
Extraordinary loss on extinguishment of debt, after tax. - - - (4.6)
----- ------ ------ ------
Net earnings . . . . . . . . . . . . . . . . . . . . . . 25.3 7.8 58.1 20.1
Less dividends on preferred stock. . . . . . . . . . . . 3.0 3.0 9.0 3.0
----- ------ ------ ------
Net earnings applicable to common shares . . . . . . . . $ 22.3 $ 4.8 $ 49.1 $ 17.1
===== ====== ====== ======
Denominator:
Weighted average common shares outstanding . . . . . . . 32.4 32.3 32.4 28.4
===== ====== ====== ======
Basic Earnings Per Share:
Before extraordinary item. . . . . . . . . . . . . . . . $ 0.69 $ 0.15 $ 1.52 $ 0.77
Extraordinary loss, aftertax . . . . . . . . . . . . . . - - - (0.17)
----- ------ ------ ------
Net. . . . . . . . . . . . . . . . . . . . . . . . . . . $ 0.69 $ 0.15 $ 1.52 $ 0.60
===== ====== ====== ======
DILUTED:
Numerator:
Net earnings applicable to common shares . . . . . . . . $ 22.3 $ 4.8 $ 49.1 $ 17.1
Plus earnings impact of assumed conversion of
preferred stock (only if dilutive). . . . . . . . . . . 3.0 - 9.0 -
----- ------ ------ ------
Net earnings applicable to common shares . . . . . . . . $ 25.3 $ 4.8 $ 58.1 $ 17.1
===== ====== ====== ======
Denominator:
Weighted average common shares outstanding . . . . . . . 32.4 32.3 32.4 28.4
Add potentially dilutive securities:
Incremental dilutive shares from assumed exercise
of stock options and other (only if dilutive) . . . . 0.6 0.6 0.4 0.6
Incremental dilutive shares from assumed conversion
of preferred stock (only if dilutive) . . . . . . . . 10.3 - 10.3 -
----- ------ ------ ------
Total diluted shares . . . . . . . . . . . . . . . . . . 43.3 32.9 43.1 29.0
===== ====== ====== ======
Diluted Earnings Per Share:
Before extraordinary item. . . . . . . . . . . . . . . . $ 0.58 $ 0.15 $ 1.35 $ 0.76
Extraordinary loss, aftertax . . . . . . . . . . . . . . - - - (0.17)
----- ------ ------ ------
Net. . . . . . . . . . . . . . . . . . . . . . . . . . . $ 0.58 $ 0.15 $ 1.35 $ 0.59
===== ====== ====== ======
</TABLE>
13
<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 29 FOR
DISCUSSION OF THE FACTORS WHICH COULD CAUSE ACTUAL RESULTS TO DIFFER MATERIALLY
FROM THOSE PROJECTED IN SUCH STATEMENTS.
OVERVIEW
The Company's strategy is to (i) maximize earnings, cash flows and return on
capital employed and increase its competitiveness by reducing costs, increasing
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. The Company is further improving profitability in the
Refining and Marketing segment by enhancing processing capabilities,
strengthening marketing channels and improving supply and transportation
functions. The Marine Services segment pursues opportunities for expansion, as
well as optimizing existing operations through development of customer services
and cost management. In the Exploration and Production segment, the strategy
focuses on generating and operating exploration projects in an effort to
diversify its oil and gas reserve base.
As part of this strategy, the Company continues to assess its existing asset
base in order to maximize returns and financial flexibility through
diversification, acquisitions and divestitures in all its segments. Through
redeployment of capital, the Company believes it will create new shareholder
value. In May 1999, the Company announced that its Board of Directors had
approved seeking alternative value-creating opportunities, including a spin-off,
trade, sale and other options, for its Exploration and Production segment. Both
the Refining and Marketing and Exploration and Production segments have growth
opportunities which require additional investment. Given the Company's
strategic objectives and its desire to improve financial flexibility, management
believes that it would not be able to prudently fund all these opportunities.
In this regard, in October 1999, the Company entered into a definitive agreement
to sell substantially all of its domestic exploration and production business to
EEX Corporation at a cash sales price of $216 million. Under the terms of the
agreement, the transaction will be structured as a stock sale. This
transaction, which is subject to certain closing conditions, is expected to
occur on or about November 30, 1999. The sales price will be adjusted for
transaction costs and certain purchase price adjustments for business activity
that occurs between July 1, 1999 and closing. Net after-tax cash proceeds are
estimated to be $170 million. The total impact of the domestic exploration and
production divestment is expected to contribute approximately $0.60 per share to
the Company's earnings on an after-tax diluted basis during the last half of
1999. This includes approximately $0.45 per diluted share for a gain from the
sale expected in the 1999 fourth quarter and $0.08 and $0.07 per diluted share
for domestic exploration and production operations during the 1999 third and
fourth quarters, respectively. Proceeds from this sale are expected to be used
to reduce Tesoro's term loans under its senior credit facility, which would
decrease the Company's debt-to-capitalization ratio to approximately 35%. The
Company is continuing to evaluate value-creating opportunities for its
exploration and production operations in Bolivia.
As part of its acquisition strategy, the Company acquired refining and marketing
assets in Hawaii in May 1998 and acquired a Washington refinery and related
assets in August 1998. These acquisitions have significantly increased Tesoro's
historical annual revenues and the scope of its Refining and Marketing
operations. The acquisitions have positioned Tesoro to participate actively in
the atypical market conditions experienced on the U.S. West Coast which
contributed significantly to profitability in the 1999 second quarter and first
half of the 1999 third quarter. Management believes that, in the first nine
months of 1999, the Company has generated synergies among the three refineries
of approximately $25 million and added approximately $1.60 per diluted share to
consolidated earnings from the acquisitions. Management estimates that it has
realized through September 30, 1999 an actual aftertax annualized investment
return on the acquisitions of approximately 13%. The Company will continue to
pursue other opportunities that are operationally and geographically
complementary with its asset base.
14
<PAGE>
BUSINESS ENVIRONMENT
The Company operates in an environment where its results and cash flows are
sensitive to volatile changes in energy prices. Fluctuations in the cost of
crude oil used for refinery feedstocks and the price of refined products can
result in changes in margins from the Refining and Marketing operations, as
prices received for refined products 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.
Changes in crude oil and natural gas prices influence the level of drilling
activity in the Gulf of Mexico. The Company's Marine Services segment, whose
customers include offshore drilling contractors and related industries, can be
impacted by significant fluctuations in crude oil and natural gas prices. The
Marine Services segment uses the first-in, first-out ("FIFO") method of
accounting for inventories of fuels. Changes in fuel prices can significantly
affect inventory valuations and costs of sales.
Changes in natural gas, condensate and oil prices impact revenues and the
present value of estimated future net revenues and cash flows from the
Exploration and Production segment. The Company may increase or decrease its
natural gas production in response to market conditions. The carrying costs of
oil and gas assets are subject to noncash write-downs based on natural gas and
oil prices and other determining factors.
15
<PAGE>
RESULTS OF OPERATIONS - THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 1999
COMPARED WITH THREE MONTHS AND NINE MONTHS ENDED SEPTEMBER 30, 1998
SUMMARY
Tesoro's net earnings were $25.3 million ($0.69 per basic share, $0.58 per
diluted share) for the three months ended September 30, 1999 ("1999 Quarter"),
compared with net earnings of $7.8 million ($0.15 per basic and diluted share)
for the three months ended September 30, 1998 ("1998 Quarter"). For the
year-to-date periods, net earnings were $58.1 million ($1.52 per basic share,
$1.35 per diluted share) for the nine months ended September 30, 1999 ("1999
Period"), compared with $20.1 million ($0.60 per basic share, $0.59 per diluted
share) for the nine months ended September 30, 1998 ("1998 Period").
The improvement in 1999 earnings was due to higher operating profit from the
Company's Refining and Marketing segment. Increased throughput and sales
volumes from operations acquired in mid-1998, refinery efficiency and
reliability, and profits from purchasing and selling products manufactured by
others contributed to the Refining and Marketing results. Partially offsetting
these improvements were increased general and administrative expenses and
interest and financing costs. On a per share basis, net earnings for the 1999
Period were impacted by the issuance of preferred stock and additional shares of
common stock in mid-1998.
Significant items which occurred in 1998 and affect the comparability with 1999
are highlighted in the table below (in millions, except per share amounts):
<TABLE>
<CAPTION>
Three Months Ended Nine Months Ended
September 30, September 30,
------------------ -----------------
1999 1998 1999 1998
---- ---- ---- ----
<S> <C> <C> <C> <C>
Net Earnings as Reported . . . . . . . . . . . . . . . . $ 25.3 $ 7.8 $ 58.1 $ 20.1
Extraordinary Loss on Debt Extinguishment, Net of
Income Tax Benefit. . . . . . . . . . . . . . . . . . . - - - 4.6
------ ------ ------ ------
Earnings Before Extraordinary Item . . . . . . . . . . . 25.3 7.8 58.1 24.7
------ ------ ------ ------
Significant Items Affecting Comparability, Pretax:
Income from receipt of contingency funds from an
operator. . . . . . . . . . . . . . . . . . . . . . . - - - 21.3
Charge for special incentive compensation . . . . . . . - - - (19.9)
------ ------ ------ ------
Total Significant Items, Pretax. . . . . . . . . . . . - - - 1.4
Income Tax Effect. . . . . . . . . . . . . . . . . . . - - - 0.5
------ ------ ------ ------
Total Significant Items, Aftertax. . . . . . . . . . . - - - 0.9
------ ------ ------ ------
Net Earnings Excluding Significant Items and
Extraordinary Item. . . . . . . . . . . . . . . . . . . 25.3 7.8 58.1 23.8
Preferred Dividend Requirements. . . . . . . . . . . . . 3.0 3.0 9.0 3.0
------ ------ ------ ------
Net Earnings Applicable to Common Stock, Excluding
Significant Items and Extraordinary Item. . . . . . . . $ 22.3 $ 4.8 $ 49.1 $ 20.8
====== ====== ====== ======
Earnings Per Share - Basic:
As reported . . . . . . . . . . . . . . . . . . . . . . $ 0.69 $ 0.15 $ 1.52 $ 0.60
Extraordinary loss. . . . . . . . . . . . . . . . . . . - - - (0.17)
Effect of other significant items . . . . . . . . . . . - - - 0.04
------ ------ ------ ------
Excluding significant items and extraordinary item. . . $ 0.69 $ 0.15 $ 1.52 $ 0.73
====== ====== ====== ======
Earnings Per Share - Diluted:
As reported . . . . . . . . . . . . . . . . . . . . . . $ 0.58 $ 0.15 $ 1.35 $ 0.59
Extraordinary loss. . . . . . . . . . . . . . . . . . . - - - (0.17)
Effect of other significant items . . . . . . . . . . . - - - 0.04
------ ------ ------ ------
Excluding significant items and extraordinary item. . . $ 0.58 $ 0.15 $ 1.35 $ 0.72
====== ====== ====== ======
</TABLE>
A discussion and analysis of the factors contributing to the Company's results
of operations are presented below.
16
<PAGE>
REFINING AND MARKETING
<TABLE>
<CAPTION>
Three Months Ended Nine Months Ended
September 30, September 30,
------------------ -------------------
(Dollars in millions except per barrel amounts) 1999 1998 1999 1998
---- ---- ---- ----
<S> <C> <C> <C> <C>
Gross Operating Revenues:
Refined products. . . . . . . . . . . . . . . . . . . . . . $ 820.0 $ 406.2 $ 1,970.0 $ 713.8
Other, primarily crude oil resales and merchandise. . . . . 18.0 18.5 51.3 58.7
------- ------- -------- -------
Gross Operating Revenues . . . . . . . . . . . . . . . . . $ 838.0 $ 424.7 $ 2,021.3 $ 772.5
======= ======= ======== =======
Segment Operating Profit:
Gross margin:
Refinery <F1>. . . . . . . . . . . . . . . . . . . . . . . $ 142.0 $ 99.3 $ 405.0 $ 182.4
Non-refinery <F2>. . . . . . . . . . . . . . . . . . . . . 23.3 4.3 54.2 15.0
------- ------- -------- -------
Total gross margins . . . . . . . . . . . . . . . . . . . 165.3 103.6 459.2 197.4
Operating expenses and other. . . . . . . . . . . . . . . . 100.2 76.6 290.2 136.6
Depreciation and amortization . . . . . . . . . . . . . . . 9.5 7.9 27.3 15.2
------- ------- -------- -------
Segment Operating Profit . . . . . . . . . . . . . . . . . $ 55.6 $ 19.1 $ 141.7 $ 45.6
======= ======= ======== =======
Total Refinery System Throughput (thousands of barrels
per day) <F3>. . . . . . . . . . . . . . . . . . . . . . . 245.6 210.0 242.4 116.4
======= ======= ======== =======
Refined Products Manufactured (thousands of barrels
per day) <F3>:
Gasoline and gasoline blendstocks . . . . . . . . . . . . 101.5 72.4 96.8 36.3
Jet fuel. . . . . . . . . . . . . . . . . . . . . . . . . 60.1 53.4 60.3 33.6
Diesel fuel . . . . . . . . . . . . . . . . . . . . . . . 37.0 29.9 34.6 14.6
Heavy oils and residual products. . . . . . . . . . . . . 40.8 48.3 43.5 29.1
Other, including synthetic natural gas and liquefied
petroleum gas. . . . . . . . . . . . . . . . . . . . . . 15.9 13.4 17.4 6.6
------- ------- -------- -------
Total Refined Products Manufactured. . . . . . . . . . . 255.3 217.4 252.6 120.2
======= ======= ======== =======
Refinery Product Spread ($/barrel) . . . . . . . . . . . . . $ 6.27 $ 5.14 $ 6.12 $ 5.74
======= ======= ======== =======
Segment Product Sales (thousands of barrels per day)<F3><F4>:
Gasoline and gasoline blendstocks . . . . . . . . . . . . . 130.5 76.0 126.1 40.0
Jet fuel. . . . . . . . . . . . . . . . . . . . . . . . . . 81.0 62.3 75.3 37.5
Diesel fuel . . . . . . . . . . . . . . . . . . . . . . . . 53.9 33.1 46.3 20.1
Heavy oils, residual products and other . . . . . . . . . . 41.9 55.6 50.5 34.5
------- ------- -------- -------
Total Product Sales. . . . . . . . . . . . . . . . . . . . 307.3 227.0 298.2 132.1
======= ======= ======== =======
Segment Gross Margins on Product Sales ($/barrel) <F5>:
Average sales price . . . . . . . . . . . . . . . . . . . . $ 29.00 $ 19.45 $ 24.20 $ 19.79
Average costs of sales. . . . . . . . . . . . . . . . . . . 23.37 14.82 18.76 14.72
------- ------- -------- -------
Gross Margin . . . . . . . . . . . . . . . . . . . . . . . $ 5.63 $ 4.63 $ 5.44 $ 5.07
======= ======= ======== =======
<FN>
<F1> Represents throughput at the Company's refineries times refinery product spread.
<F2> Non-refinery margin includes merchandise margins, margins on products purchased and resold, and
adjustments due to selling a volume and mix of product that is different than actual volumes
manufactured.
<F3> Volumes for 1998 include amounts from the Hawaii operations (acquired in May 1998) and the Washington
refinery (acquired in August 1998) averaged over the periods presented.
<F4> Sources of total product sales include products manufactured at the refineries, products drawn from
inventory balances and products purchased from third parties.
<F5> Gross margins on total product sales include margins on sales of manufactured and purchased products
and the effects of inventory changes.
</TABLE>
17
<PAGE>
THREE MONTHS ENDED SEPTEMBER 30, 1999 COMPARED WITH THREE MONTHS ENDED SEPTEMBER
30, 1998. Segment operating profit for the Company's Refining and Marketing
operations was $55.6 million in the 1999 Quarter, an increase of $36.5 million
from segment operating profit of $19.1 million in the 1998 Quarter. The
improvement in results from Refining and Marketing was primarily due to the
combined effects of higher throughput and sales volumes and improved product
margins. Sales volumes increased due to the activity of the Washington refinery
acquired in August 1998 and additional sales of product, either purchased from
third parties or from inventory stock, to supply U.S. West Coast markets. The
Company's system-wide refinery throughput for the 1999 Quarter averaged 245,600
barrels per day, an increase of 35,600 barrels per day over the 1998 Quarter
which only included two months of operations for the Washington refinery. The
Company's refinery margin increased to $6.27 per barrel in the 1999 Quarter,
compared to $5.14 per barrel in the 1998 Quarter, primarily due to strong West
Coast margins during July and the first part of August 1999. Refining margins
during this period were strong in the western U.S. due to seasonal demand,
product supply disruptions caused by operating problems at other refineries, and
a rupture of the major refined products pipeline which serves the Pacific
Northwest region. During September 1999, however, West Coast refining margins
fell to below normal levels as product supplies increased and crude oil prices
escalated.
Revenues from sales of refined products in the Refining and Marketing segment
increased in the 1999 Quarter, compared to the 1998 Quarter, primarily due to
the higher sales volumes related to the Washington refinery acquisition and
higher product prices. The decline in other revenues was primarily due to crude
oil resales in the 1998 Quarter with no comparable sales in the 1999 Quarter.
The increase in costs of sales reflected increased prices for refinery
feedstock, the higher volumes associated with the acquisition and higher
purchased product volumes.
Aggregate refinery gross margin increased to $142.0 million in the 1999 Quarter
due to the higher throughput volumes and an increase in average refinery product
spread per barrel. Non-refinery margins increased to $23.3 million in the 1999
Quarter due primarily to refined product sales in excess of refinery production
and higher sales of purchased products. Included in the 1999 Quarter
non-refinery margin was approximately $11 million generated by marketing
purchased refined products, compared to $1 million in the 1998 Quarter.
Operating expenses and depreciation and amortization increased primarily due to
the Washington acquisition.
NINE MONTHS ENDED SEPTEMBER 30, 1999 COMPARED WITH NINE MONTHS ENDED SEPTEMBER
30, 1998. Segment operating profit for the Company's Refining and Marketing
operations was $141.7 million in the 1999 Period, an increase of $96.1 million
from segment operating profit of $45.6 million in the 1998 Period. This
increase was primarily due to the operating results from the Hawaii and
Washington refineries acquired in mid-1998 and stronger than normal market
conditions on the West Coast during the 1999 second quarter and first half of
the 1999 third quarter. Refining margins during this period were strong in the
western U.S. due to seasonal demand, product supply disruptions caused by
operating problems at other refineries, and a rupture of the major refined
products pipeline which serves the Pacific Northwest region.
Revenues from sales of refined products in the Refining and Marketing segment
increased in the 1999 Period, primarily due to the higher sales volumes from the
acquisitions and higher product prices. During the 1999 Period, sales from the
Company's 63 retail stations in Alaska and Hawaii contributed average monthly
fuel volumes of approximately 130,000 gallons per station and average monthly
merchandise sales of approximately $66,000 per station. Other revenues included
higher retail merchandise sales, primarily from the Hawaii acquisition, offset
by lower crude oil resales. The increase in costs of sales reflected higher
volumes associated with the acquisitions, increased prices for feedstock and
higher purchased product volumes.
Overall refinery gross margin increased to $405.0 million in the 1999 Period due
to the higher throughput volumes and an increase in average refinery product
spread per barrel to $6.12 in the 1999 Period compared to $5.74 per barrel in
the 1998 Period. Margins from non-refinery activities increased to $54.2
million in the 1999 Period due primarily to higher sales of purchased product
and increased merchandise sales. Included in non-refinery margin was
approximately $29 million from sales of purchased refined products, compared to
$3 million in the prior-year period. Operating expenses and depreciation and
amortization also increased primarily due to the acquisitions.
The Refining and Marketing segment benefited during the 1999 Period from
Tesoro's focus on manufacturing efficiency and reliability, as well as marketing
flexibility. Throughput for the Company's refinery-system
18
<PAGE>
averaged 242,400 barrels per day during the 1999 Period and was supplied 38%
from foreign sources, 29% from Alaska's North Slope, 19% from Canada, 13% from
Alaska's Cook Inlet and 1% from other sources.
OUTLOOK AND OTHER FACTORS. During the 1999 Quarter, the Company maintained a
flexible supply of crude oils and other feedstocks, focused on manufacturing and
distribution costs and operated the refineries at economic rates, which all
contributed to the improvement in operating profit. Margins, however, in the
latter half of the 1999 Quarter, were adversely impacted as industry refining
capacity on the West Coast came back on-line, refined product imports into the
West Cost continued and crude costs escalated. The Company's refinery product
spread, which averaged approximately $8.07 per barrel in the month of July 1999
and $7.16 per barrel in the month of August 1999, dropped precipitously to
approximately $3.38 per barrel in the month of September 1999. Management
believes that the impact of product seasonality, a scheduled turnaround at the
Company's Washington refinery and continuing high crude oil prices could cause
the Company's product margins to remain at low levels during the 1999 fourth
quarter. Management estimates that the Company's refinery product spread
averaged $4.50 to $5.00 per barrel during October 1999. Market conditions and
other additional factors that are beyond the control of the Company will
continue to influence, either positively or negatively, the future profitability
of the Refining and Marketing segment.
The scheduled turnaround at the Washington refinery involves normal maintenance
of the crude distillation and catalytic reformer unit for approximately 25 days
during the 1999 fourth quarter. Also, during the 1999 fourth quarter, the
Company is completing the installation of a distillate treater at the Washington
refinery which will enable the refinery to increase its production of low-sulfur
diesel fuel and jet fuel. Management estimates that the distillate treater
installation, together with licensing fees and supporting infrastructure, will
cost approximately $13 million and will be completed by year-end 1999. The
Company has spent approximately $5 million for the installation through
September 30, 1999. Management believes that the distillate treater
installation will have a payback period of approximately two years, beginning in
2000.
In the 1999 third quarter, the Company entered into a charter for a double-hull
tanker to be used for transporting crude oil and refined products. Under the
terms of the new charter, Tesoro will receive one of the new Lightship Class
tankers that entered service in October 1998. The new charter, which has a
three-year primary term beginning in May 2000 and two one-year options, will
require future minimum annual lease payments of approximately $10 million. The
new charter will save the Company approximately $5 million to $6 million
annually when it replaces the Chesapeake Trader, which goes off charter to
Tesoro in May 2000. Tesoro has another ship under charter, the Potomac Trader,
which goes off charter to Tesoro in September 2000. Management is continuing to
evaluate the Company's requirements for chartered vessels and believes that,
based on current market conditions, shipping costs could be further reduced in
2000 and 2001.
For the year 2000, management projects that its refinery-system throughput will
average approximately 260,000 barrels per day and refined products manufactured
will average 270,000 barrels per day. One maintenance turnaround is scheduled
in 2000 for the hydrocracker and catalytic reformer at the Hawaii refinery.
Feedstock for the refineries is expected to consist of approximately 42% from
foreign sources, 25% from the Alaska's North Slope, 15% from Canada, 12% from
Alaska's Cook Inlet and 6% from other sources. The Company's refinery-system
yield is expected to consist of approximately 36% gasoline, 26% jet fuel, 15%
diesel fuel and 23% heavy oils and other during 2000.
19
<PAGE>
MARINE SERVICES
<TABLE>
<CAPTION>
Three Months Ended Nine Months Ended
September 30, September 30,
------------------ -----------------
(Dollars in millions) 1999 1998 1999 1998
---- ---- ---- ----
<S> <C> <C> <C> <C>
Gross Operating Revenues:
Fuels . . . . . . . . . . . . . . . $ 48.8 $ 21.4 $ 86.3 $ 69.7
Lubricants and other. . . . . . . . 3.4 4.0 10.2 11.9
Services. . . . . . . . . . . . . . 3.3 3.1 7.9 8.8
----- ----- ----- -----
Gross Operating Revenues . . . . . 55.5 28.5 104.4 90.4
Costs of Sales . . . . . . . . . . . 41.4 17.8 73.4 60.8
----- ----- ----- -----
Gross Profit . . . . . . . . . . . 14.1 10.7 31.0 29.6
Operating Expenses and Other . . . . 9.3 6.9 24.2 21.3
Depreciation and Amortization. . . . 0.6 0.7 2.0 1.8
----- ----- ----- -----
Segment Operating Profit. . . . . . $ 4.2 $ 3.1 $ 4.8 $ 6.5
===== ===== ===== =====
Sales Volumes (millions of gallons):
Fuels, primarily diesel . . . . . . 95.9 43.8 177.9 135.3
Lubricants. . . . . . . . . . . . . 0.5 0.5 1.5 1.7
</TABLE>
Effective June 17, 1999, the Company purchased the U.S. West Coast marine fuels
operations of BP Marine, a division of BP Amoco PLC. The purchase, which
included inventory and leased facilities at Port Angeles and Seattle,
Washington, and Portland, Oregon, expanded the Marine Services segment's
presence on the West Coast. Results from these operations, which have been
included in Tesoro's Marine Services results since the date of purchase,
contributed $23 million and $26 million to revenues during the 1999 Quarter and
1999 Period, respectively, and added 54 million and 61 million gallons to sales
volumes during the 1999 Quarter and 1999 Period, respectively. The increase in
operating expenses and other during the 1999 Quarter and 1999 Period also
reflected the additional West Coast operations. The $1.1 million improvement in
segment operating profit during the 1999 Quarter was largely attributable to
these West Coast operations which benefited from low costs of sales during a
period of rising prices. Management believes that the new West Coast operations
will continue to be accretive to earnings and add approximately $0.5 million to
future quarterly segment operating profit.
Excluding the impact of the new West Coast operations, revenues would have
increased by $4.0 million and segment operating profit would have declined by
$0.3 million in the 1999 Quarter as compared with the 1998 Quarter. This
quarterly increase in revenues was primarily due to higher spot fuel prices,
while the decline in segment operating profit was mainly due to lower fuel sales
volumes and other product margins. On a nine-month basis, excluding the impact
of the new West Coast operations, revenues and segment operating profit would
have declined by $12 million and $3.3 million, respectively, during the 1999
Period as compared with the 1998 Period mainly due to lower fuel sales volumes,
other product margins and service revenues. The Marine Services operations in
the Gulf of Mexico, which are largely dependent upon the volume of oil and gas
drilling, workover, construction and seismic activity in the Gulf, were
negatively impacted by the low level of drilling activity during the 1999
Period. However, the business climate improved during the 1999 Quarter with the
number of drilling rigs served by Tesoro's terminals increasing to a high of 33
as compared to eight in March 1999.
20
<PAGE>
EXPLORATION AND PRODUCTION
<TABLE>
<CAPTION>
Three Months Ended Nine Months Ended
September 30, September 30,
------------------ -----------------
(Dollars in millions except per unit amounts) 1999 1998 1999 1998
---- ---- ---- ----
<S> <C> <C> <C> <C>
U.S. <F1>:
Gross operating revenues . . . . . . . . . . . . . . . . . $ 15.8 $ 16.5 $ 43.5 $ 54.3
Other income (expense) . . . . . . . . . . . . . . . . . . 0.1 - (0.5) 22.3
Production costs . . . . . . . . . . . . . . . . . . . . . 2.6 2.3 7.7 6.8
Administrative support and other operating expenses. . . . 0.8 0.4 2.0 1.4
Depreciation, depletion and amortization . . . . . . . . . 6.5 8.5 19.9 26.7
------ ------ ------ ------
Segment Operating Profit - U.S.. . . . . . . . . . . . . . 6.0 5.3 13.4 41.7
------ ------ ------ ------
LATIN AMERICA:
Gross operating revenues. . . . . . . . . . . . . . . . . . 2.9 2.8 5.5 8.8
Other income (expense). . . . . . . . . . . . . . . . . . . 0.4 - 0.4 (0.5)
Production costs. . . . . . . . . . . . . . . . . . . . . . 0.2 0.3 0.9 0.8
Administrative support and other operating expenses . . . . 0.7 0.6 2.3 2.0
Depreciation, depletion and amortization. . . . . . . . . . 0.7 0.8 1.5 2.0
------ ------ ------ ------
Segment Operating Profit - Latin America . . . . . . . . . 1.7 1.1 1.2 3.5
------ ------ ------ ------
Total Segment Operating Profit - Exploration and Production. $ 7.7 $ 6.4 $ 14.6 $ 45.2
====== ====== ====== ======
U.S.:
Average Daily Net Production:
Natural gas (million cubic feet, "MMcf") . . . . . . . . . 72.8 83.6 74.9 91.9
Oil (thousand barrels) . . . . . . . . . . . . . . . . . . 0.6 0.2 0.6 0.2
Total (million cubic feet equivalent, "MMcfe"). . . . . . 76.3 85.0 78.2 93.2
Average Prices:
Natural gas ($/thousand cubic feet, "Mcf") <F2>. . . . . . $ 2.11 $ 2.02 $ 1.92 $ 2.03
Oil ($/barrel) . . . . . . . . . . . . . . . . . . . . . . $ 19.89 $ 11.07 $ 15.96 $ 12.46
Average Operating Expenses ($/thousand cubic feet
equivalent, "Mcfe"):
Lease operating expenses . . . . . . . . . . . . . . . . . $ 0.29 $ 0.27 $ 0.30 $ 0.23
Severance taxes. . . . . . . . . . . . . . . . . . . . . . 0.09 0.03 0.06 0.04
------ ------ ------ ------
Total production costs. . . . . . . . . . . . . . . . . . 0.38 0.30 0.36 0.27
Administrative support and other . . . . . . . . . . . . . 0.09 0.06 0.09 0.05
------ ------ ------ ------
Total Operating Expenses. . . . . . . . . . . . . . . . . $ 0.47 $ 0.36 $ 0.45 $ 0.32
====== ====== ====== ======
Depletion ($/Mcfe). . . . . . . . . . . . . . . . . . . . . $ 0.90 $ 1.07 $ 0.90 $ 1.03
====== ====== ====== ======
LATIN AMERICA:
Average Daily Net Production:
Natural gas (MMcf) . . . . . . . . . . . . . . . . . . . . 24.4 31.9 16.3 27.1
Condensate (thousand barrels). . . . . . . . . . . . . . . 0.6 0.6 0.5 0.7
Total (MMcfe) . . . . . . . . . . . . . . . . . . . . . . 28.0 35.8 19.1 31.4
Average Prices:
Natural gas ($/Mcf). . . . . . . . . . . . . . . . . . . . $ 0.72 $ 0.76 $ 0.76 $ 0.84
Condensate ($/barrel). . . . . . . . . . . . . . . . . . . $ 20.35 $ 11.47 $ 16.64 $ 12.83
Average Operating Expenses ($/Mcfe):
Production costs . . . . . . . . . . . . . . . . . . . . . $ 0.07 $ 0.07 $ 0.17 $ 0.09
Administrative support and other . . . . . . . . . . . . . 0.21 0.22 0.36 0.25
------ ------ ------ ------
Total Operating Expenses. . . . . . . . . . . . . . . . . $ 0.28 $ 0.29 $ 0.53 $ 0.34
====== ====== ====== ======
Depletion ($/Mcfe). . . . . . . . . . . . . . . . . . . . . $ 0.27 $ 0.22 $ 0.27 $ 0.22
====== ====== ====== ======
<FN>
<F1> Represents the Company's U.S. oil and gas operations combined with gas transportation activities.
<F2> Includes effects of commodity price agreements which amounted to a loss of $0.28 per Mcf and a gain
of $0.09 per Mcf for the three months ended September 30, 1999 and 1998, respectively, and a loss of
$0.08 per Mcf and a gain of $0.03 per Mcf during the nine months ended September 30, 1999 and 1998,
respectively.
</TABLE>
21
<PAGE>
U.S.
See Note C of Notes to Condensed Consolidated Financial Statements for
information on an agreement to sell substantially all of the Company's domestic
exploration and production business which is expected to close on or about
November 30, 1999.
THREE MONTHS ENDED SEPTEMBER 30, 1999 COMPARED WITH THREE MONTHS ENDED SEPTEMBER
30, 1998. Segment operating profit from the Company's U.S. exploration and
production operations was $6.0 million in the 1999 Quarter compared with $5.3
million in the 1998 Quarter. The Company's U.S. net production volumes
decreased approximately 10% to 76.3 MMcfe per day in the 1999 Quarter, compared
to 85.0 MMcfe per day in the 1998 Quarter, primarily due to Bob West Field
production which declined approximately 11.5 MMcfe per day. Production from
other fields increased as three significant discoveries made in Texas during the
1999 second quarter increased production levels for the later half of the year.
Gross operating revenues from the Company's U.S. operations decreased by $0.7
million due to the lower production, partially offset by a 4% increase in
natural gas prices to $2.11 per Mcf in the 1999 Quarter from $2.02 per Mcf in
the 1998 Quarter. Net production costs per Mcfe increased to $0.38 from $0.30
primarily due to decreased production volumes. Depreciation, depletion and
amortization decreased by $2.0 million, or 24%, due to lower volumes and a
reduced depletion rate.
NINE MONTHS ENDED SEPTEMBER 30, 1999 COMPARED WITH NINE MONTHS ENDED SEPTEMBER
30, 1998. Segment operating profit from the Company's U.S. exploration and
production operations was $13.4 million in the 1999 Period compared with $41.7
million in the 1998 Period. The 1998 Period benefited from receipt of $21.3
million from an operator in the Bob West Field, representing funds no longer
needed as a contingency reserve for litigation. Excluding the $21.3 million
receipt from the 1998 Period, segment operating profit decreased by $7.0 million
during the 1999 Period. This decrease was primarily due to lower natural gas
prices and lower production volumes. The Company's U.S. net production volumes
decreased 16% to 78.2 MMcfe per day in the 1999 Period, compared to 93.2 MMcfe
per day in the 1998 Period, primarily due to declines in the Bob West Field and,
to a lesser extent, to lower capital spending in other fields.
Gross operating revenues from the Company's U.S. operations decreased by $10.8
million due to lower production and a 5% decline in natural gas prices to $1.92
per Mcf in the 1999 Period compared to $2.03 per Mcf in the 1998 Period. Net
production costs per Mcfe increased to $0.36 from $0.27 primarily due to
decreased volumes. Depreciation, depletion and amortization decreased by $6.8
million, or 25%, due to lower volumes and a reduced depletion rate. The
depletion rate was reduced in part by the fourth quarter 1998 ceiling test
write-down of capitalized costs and in part by reserve additions during the 1999
Period.
For information related to natural gas commodity price agreements, see Item 3
contained herein.
LATIN AMERICA
The take-or-pay contract ("Argentina Contract") between Yacimientos Petroliferos
Fiscales Bolivianos ("YPFB"), a Bolivian government agency, and YPF, a
publicly-held company based in Argentina, expired on August 31, 1999. The
Company's sale of natural gas production in Bolivia had been based on the volume
and pricing terms in the Argentina Contract. Since September 1999, all of the
Company's Bolivian natural gas production has been sent to Brazil through a new,
third-party pipeline which began operations in July 1999 and provides access to
potentially larger gas-consuming markets. These pipeline sales are governed by
a 20-year take-or-pay contract ("Brazil Contract") between YPFB and Petroleo
Brasileiro, S.A. ("Petrobras"). Under the Brazil Contract, the Company had a
preferential right to deliver 22.8% of the first 200 MMcf per day sold under the
Brazil Contract. The second tranche allocation was recently determined by YPFB
which increased Tesoro's allocated share of production by 5 MMcf per day to a
total of 51 MMcf per day. Although the new Bolivia-to-Brazil pipeline creates
the potential for increased Tesoro gas sales, management believes that the
Company's Bolivian production in the 1999 fourth quarter will be significantly
below its allocated amount due to low Brazilian summer demand.
The Company is continuing to evaluate value-creating opportunities for its
exploration and production operations in Bolivia (see Note C of Notes to
Condensed Consolidated Financial Statements).
22
<PAGE>
THREE MONTHS ENDED SEPTEMBER 30, 1999 COMPARED WITH THREE MONTHS ENDED SEPTEMBER
30, 1998. Segment operating profit from the Company's Latin American operations
was $1.7 million, compared with $1.1 million in the 1998 Quarter. This increase
in segment operating profit included benefits from a royalty reclassification,
under provisions of Bolivia's Hydrocarbon Laws, of Tesoro's production for
certain prior periods. Revenues increased during the 1999 Quarter primarily due
to higher crude oil prices, offset by lower production volumes and lower natural
gas prices. Bolivian natural gas prices, which are contractually indexed to
certain posted fuel oil prices, decreased to $0.72 per Mcf in the 1999 Quarter
from $0.76 per Mcf in the 1998 Quarter. Net production volumes decreased 22% to
28.0 MMcfe per day, from 35.8 MMcfe per day, primarily due to the transition
from Argentine markets to Brazilian markets. Compared to the first half of
1999, however, production volumes in the 1999 Quarter reflected a significant
increase. Lower production in the first half of 1999 resulted in an imbalance
in the take-or-pay contract with YPFB, which was made up during the 1999
Quarter.
NINE MONTHS ENDED SEPTEMBER 30, 1999 COMPARED WITH NINE MONTHS ENDED SEPTEMBER
30, 1998. Segment operating profit from the Company's Latin American operations
was $1.2 million, compared with $3.5 million in the 1998 Period. This decrease
in segment operating profit was due to lower production and natural gas prices.
Bolivian natural gas prices fell approximately 10% to $0.76 per Mcf in the 1999
Period from $0.84 per Mcf in the 1998 Period. As discussed above, net
production volumes decreased 39% from 31.4 MMcfe per day to 19.1 MMcfe per day.
GENERAL AND ADMINISTRATIVE EXPENSES
General and administrative expenses increased by $3.5 million and $11.6 million
during the 1999 Quarter and 1999 Period, respectively. These increases were
primarily due to costs of implementing an integrated enterprise-wide software
system, together with higher employee costs associated with organizational
development and growth.
INTEREST AND FINANCING COSTS
Interest and financing costs increased by $1.1 million and $15.8 million during
the 1999 Quarter and 1999 Period, respectively. These increases primarily
reflected the higher debt levels which funded the 1998 Hawaii and Washington
acquisitions.
OTHER EXPENSE
The $3.5 million increase in other expense over the prior year quarter was
primarily due to a provision for legal costs recorded in the 1999 Quarter. On a
nine-month basis, other expense decreased by $16.6 million primarily due to a
charge of $19.9 million for special incentive compensation (of which $7.9
million related to operating segment employees) recorded in the 1998 Period,
partly offset by the provision for legal costs in the 1999 Period.
INCOME TAX PROVISION
The increase of $12.1 million in the income tax provision in the 1999 Quarter,
compared with the 1998 Quarter, reflected the increase in pretax earnings,
primarily from the Refining and Marketing segment. Similarly, the income tax
provision increased $18.2 million to $37.3 million in the 1999 Period due to the
Company's higher consolidated earnings partially offset by reduced foreign taxes
due to lower Bolivian natural gas production.
In response to low product prices, the Bolivian government has given the Company
approval to produce "new hydrocarbons" in place of "existing hydrocarbons" (as
defined by the Hydrocarbon Law) for gross volumes over 20 MMcf per day through
the end of 1999. "New hydrocarbons" are subject to a combined royalty and tax
rate of 18% while "existing hydrocarbons" are subject to a combined royalty and
tax rate of 60%. Although this change will have a favorable effect on Bolivia
tax rates, it is not expected to have a material effect on the Company's
consolidated income tax provision in 1999.
23
<PAGE>
CAPITAL RESOURCES AND LIQUIDITY
OVERVIEW
The Company's primary sources of liquidity are its cash flows from operations
and borrowing availability under a revolving line of credit. Capital
requirements are expected to include capital expenditures, working capital, debt
service and preferred dividend payments. Based upon current needs, management
believes that the available capital resources will be adequate to meet its
capital requirements.
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.
CAPITAL SPENDING
During the first nine months of 1999, the Company's capital expenditures totaled
$100 million which were financed primarily with internally-generated cash flows.
Capital expenditures for the Exploration and Production segment were
approximately $48 million, including $33 million for U.S. operations and $15
million for Bolivia operations. During the 1999 Period, the Company
participated in drilling 17 exploratory wells (twelve completed) and eight
developments wells (five completed) in the U.S. and one exploratory well in
Bolivia which was completed. Capital improvements for the Refining and
Marketing segment in the 1999 Period totaled $43 million, which included the
acquisition of a terminal in Alaska and various refinery and retail gas station
projects. Other capital spending during the 1999 Period was primarily related
to the implementation of the integrated enterprise-wide system and purchase of
the West Coast marine fuel operations.
The Company's capital spending is under continuing review, considering
requirements and business conditions in each operating segment. Although
capital expenditures for the year 1999 had been projected at $170 million,
actual expenditures will be less due to a number of factors. The Company
expects to spend approximately $48 million for capital projects during the
fourth quarter of 1999, which include the costs for exploration and production
activities, refining and marketing projects and implementation of the integrated
enterprise-wide system. These capital expenditures are expected to be funded
primarily with cash flows from operations supplemented with borrowings, if
necessary, under the Company's revolving credit facility.
For the year 2000, management estimates that its capital spending program will
range between $80 million and $90 million, primarily for refinery improvements
and retail marketing expansion, and will be funded with internally-generated
cash flows from operations. Management estimates that the return on investment
will range from 15% to 20% for retail capital expenditures and 25% to 50% for
manufacturing capital expenditures.
CREDIT ARRANGEMENTS AND CAPITAL STRUCTURE
Significant changes in the Company's credit arrangements and improvements in its
capital structure since the 1998 year-end are highlighted below:
. Under the Senior Credit Facility ("Credit Facility"), the Company repaid $61
million net under the revolving credit and letter of credit facility
("Revolver") and borrowed an additional $29 million net under term loans
("Term Loans") during the 1999 Period.
. In April 1999, the Company reduced commitments under the Revolver from $300
million to $175 million.
24
<PAGE>
On October 1, 1999, the Company and its lenders amended the Credit Facility to
permit the Company to sell its Exploration and Production segment in one or more
transactions. The amendment requires the Company to use the proceeds from the
sale of the Exploration and Production segment to reduce the Term Loans
outstanding under the Credit Facility. See Note C of Notes to Condensed
Consolidated Financial Statements for further information related to the
Company's strategic objectives to improve its capital structure, provide
additional financial flexibility, and increase its focus on downstream
operations.
At September 30, 1999, the Company had no borrowings under the Revolver and
$178.6 million outstanding under Term Loans. Since the Company expects to fund
capital expenditures primarily with internally-generated cash flows, the Company
elected to reduce availability under the Revolver in April 1999, which reduces
commitment fees. Based on current needs, the remaining credit capacity is
expected to be sufficient to fund capital expenditures and working capital
requirements. At September 30, 1999, unused availability under the Revolver was
$172 million and the Company's total debt to capitalization ratio was 46%.
The 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. The Company was in
compliance with these financial covenants at September 30, 1999, and the Company
expects to be in compliance with these covenants through the remainder of 1999.
Future compliance with the financial covenants, which start becoming more
restrictive during the fourth quarter of 1999, will continue to be dependent on
the Company's cash flows which are sensitive to changes in market conditions.
The terms of the Credit Facility allow for payment of cash dividends on the
Company's Common Stock not to exceed an aggregate of $10 million in any year and
also allow for payment of required dividends on its Preferred Stock. The Board
of Directors has no present plans to pay dividends on Common Stock. However,
from time to time the Board of Directors reevaluates the feasibility of
declaring future dividends.
Provisions of the Credit Facility require prepayments of the Term Loans, with
certain defined exceptions, in an amount equal to: (i) 100% of the net proceeds
of certain incurred indebtedness; (ii) 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 the Company's subsidiaries; and
(iii) a percentage of excess cash flows, as defined, depending on certain credit
statistics. With the exception of the exploration and production sale discussed
above, the Company anticipates that no prepayments will be required for 1999.
CASH FLOWS
Components of the Company's cash flows are set forth below (in millions):
<TABLE>
<CAPTION>
Nine Months Ended
September 30,
-----------------
1999 1998
---- ----
<S> <C> <C>
Cash Flows From (Used In):
Operating Activities . . . . . . . . . . . . . $ 147.6 $ 98.7
Investing Activities . . . . . . . . . . . . . (99.6) (659.4)
Financing Activities . . . . . . . . . . . . . (45.3) 555.8
------- -------
Increase (Decrease) in Cash and Cash Equivalents $ 2.7 $ (4.9)
======= =======
</TABLE>
Net cash from operating activities totaled $148 million during the 1999 Period,
compared to $99 million for the 1998 Period, primarily due to improved earnings.
Cash flows from earnings before depreciation, depletion and amortization and
other noncash charges increased $36 million in the 1999 Period, compared with
the 1998 Period. Net cash used in investing activities of $100 million during
the 1999 Period included capital expenditures of $43 million in Refining and
Marketing and $48 million in Exploration and Production. Financing activities
in the 1999 Period included gross repayments of $319 million under the Revolver
offset by gross borrowings of $258 million. In addition, $50 million was issued
under the Term Loans, partly offset by debt payments of $21 million. Payments
of dividends on preferred stock totaled $9 million in the 1999 Period. At
September 30, 1999, the Company's working capital totaled $162 million, which
included cash and cash equivalents of approximately $16 million. The working
capital ratio was 1.5:1 at September 30, 1999 compared to 1.9:1 at December 31,
1998. The change in the ratio reflected increases in receivables and payables
largely due to higher product and crude oil prices.
25
<PAGE>
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 in remedial responses and has incurred cleanup expenditures
associated with environmental matters at a number of sites, including certain of
its owned properties. At September 30, 1999, the Company's accruals for
environmental expenses totaled $12.2 million. Based on currently available
information, including the participation of other parties or former owners in
remediation actions, the Company believes these accruals are adequate.
To comply with environmental laws and regulations, the Company anticipates it
will make capital improvements totaling approximately $8 million in 1999 and $5
million in 2000. In addition, capital expenditures for alternative secondary
containment systems for existing storage tank facilities are estimated to be $1
million in 1999 and $2 million in 2000, with a remaining $3 million expected to
be spent by 2002.
The Company is currently evaluating certain proposed revisions to the Clean Air
Act regulations which would require a reduction in the sulfur content in
gasoline fuel manufactured at its refineries. Although the proposed revisions
are not finalized, the Company expects that it will make capital improvements to
certain equipment at its Washington refinery to meet the expected gasoline
standard. Additional proposed changes to the Clean Air Act regulations may
include new emission controls at certain processing units at each of the
Company's refineries. The Company anticipates that the revisions to the Clean
Air Act will become effective over the next three to five years and that, based
on known current technology, it could spend approximately $25 million to $30
million to comply with these proposed revisions.
For further information on environmental and other contingencies, see Note F of
Notes to Condensed Consolidated Financial Statements in Part I, Item 1, and
Legal Proceedings in Part II, Item 1, included herein.
YEAR 2000 READINESS DISCLOSURE
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 production and distribution, information
management services and financial reporting, as well as in various
administrative functions. The goal of the Company's Year 2000 project is to
prevent any disruption to the Company's business processes or its ability to
conduct business resulting from Year 2000 computer issues.
The Year 2000 may cause problems in systems that use dates. Many systems such
as computers, computer applications, process equipment used in refineries, phone
systems, and electrical components have embedded chips that are subject to
failure. Failures result from the practice of representing the year as a
2-digit number, and then treating "00" as the year 1900, not 2000. Other
failures may result if the Year 2000 is not recognized as a leap year.
Disruptions may also be caused by computer failures of external sources such as
vendors, service providers and customers.
To identify and eliminate potential disruptions, the Company developed a Year
2000 compliance plan ("Compliance Plan") with respect to those Systems and
Programs that are deemed to be critical to the Company's operations and safety.
The Compliance Plan, which covers information technology ("IT") and non-IT
aspects, is divided into the following sections: Plant Facilities (includes
non-IT embedded systems such as process control systems, environmental systems
and the physical equipment and facilities at the Company's exploration and
production locations, refineries and transportation vessels), Business Systems
(includes IT hardware, software, and network systems serving the Company's
business units), Office Facilities (includes telephone, security, and office
equipment) and External Sources (customers, suppliers and vendors).
26
<PAGE>
Implementation of the Compliance Plan is led by an oversight committee, made up
of representatives from each of the Company's major facilities. The Compliance
Plan is monitored weekly and progress is reported to management and the Board of
Directors. The Compliance Plan, which is 99% to 100% complete, includes the
following phases:
. Awareness: Establish a Year 2000 team and develop a detailed plan
. Assessment: Identify critical business processes and systems that
must be modified; assess and prioritize risk factors
. Remediation: Convert, replace or eliminate hardware and software
. Validation: Test and verify
. Implementation: Put new and renovated systems into production;
monitor and continually evaluate
. Contingency Plans: Develop contingency plans for critical items
that cannot be tested
The first two phases of the Compliance Plan have been completed for several
months. Remediation and implementation were completed in October 1999.
Although this completed the remediation efforts, the Company will continue its
efforts to identify and correct any newly-developed items or items that may have
been overlooked. Contingency plans have been completed at the various sites for
the core business processes. An overall contingency plan for the Company has
been developed to provide a centralized communication center for monitoring,
gathering and disseminating information for the entire Tesoro organization
during the Year 2000 "rollover." Contingency plans were substantially completed
in October 1999 and will be tested before the year-end 1999.
The Company has utilized both internal and external resources in evaluating its
Systems and Programs, as well as manual processes, external interfaces with
customers and services supplied by vendors, to identify potential Year 2000
compliance problems. Modification or replacement of the Company's Systems and
Programs has been performed in-house by Company personnel and 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 will be Year 2000 compliant. Approximately 3,000
questionnaires were sent to vendors who were identified as providing goods and
services to the Company's operations. Vendors were asked questions relating to
their Year 2000 preparation and readiness. Over 95% of the vendors either
returned the questionnaire or were contacted and interviewed. All of the
vendors contacted, including all of the vendors identified as being critical,
provided a positive response. None could foresee having problems providing
goods and services on or after January 1, 2000. The utility companies servicing
the Company's various sites were contacted and all responded favorably about
their ability to provide uninterrupted service.
Ninety percent of Tesoro's customers, including all of the critical customers,
were contacted to determine their Year 2000 preparedness. All customers
contacted indicated that they will be ready and do not anticipate any
significant problems. Management believes that the Company's risk is minimal as
it relates to key vendors, suppliers and customers.
The Company expects that 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. Costs to become Year 2000
compliant are estimated to total $5 million, of which $3 million was spent
through September 30, 1999. It is estimated that approximately 60% of these
costs are capital expenditures. The costs of Year 2000 compliance are the best
estimates of the Company's management and are believed to be reasonably
accurate. The costs of implementing the integrated enterprise-wide system are
excluded as this system implementation was undertaken primarily to improve
business processes.
If the Company did not satisfactorily complete its Compliance Plan, including
identifying and resolving problems encountered by the Company's external service
providers, potential consequences could include, among other things, unit
downtime at, or damage to, the Company's refineries, gas stations, terminal
facilities and pipelines;
27
<PAGE>
delays in transporting refinery feedstocks and refined products; reduction in
natural gas production; impairment of relationships with significant suppliers
or customers; loss of accounting data or delays in processing such data; and
loss of or delays in internal and external communications. The occurrence of
any or all of the above could result in a material adverse effect on the
Company's results of operations, liquidity or financial condition. Although the
Company believes that it has satisfactorily completed its Compliance Plan, there
can be no assurance that it has addressed every potential issue or that the Year
2000 problem will not adversely affect the Company and its business.
The foregoing statements in the above paragraphs under "Year 2000 Readiness
Disclosure" herein are intended to be and are hereby designated "Year 2000
Readiness Disclosure" statements within the meaning of the Year 2000 Information
and Readiness Disclosure Act.
NEW ACCOUNTING STANDARD
In June 1998, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standard ("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 the Company on January 1, 2001 and cannot be applied retroactively
to financial statements of prior periods. From time to time, the Company enters
into agreements to reduce commodity price risks. Gains or losses on these
hedging activities are recognized when the related physical transactions are
recognized as sales or purchases. The Company is evaluating the effects that
this new statement will have on its financial condition, results of operations
and financial reporting and disclosures.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The Company utilizes various financial instruments and enters into agreements
which inherently have some degree of market risk. The primary sources of market
risk include fluctuations in commodity prices and interest rate fluctuations.
PRICE FLUCTUATIONS
The Company's results of operations are highly dependent upon prices received
for refined products and natural gas production and on the prices paid for crude
oil and other refinery feedstocks.
From time to time, the Company enters into commodity price agreements to reduce
the risk caused by fluctuations in the prices of natural gas in the spot market.
During the 1999 Period, the Company used such agreements to set the price of
approximately 40% of the natural gas production that it sold in the spot market
and recognized a loss of $1.7 million ($0.08 per Mcf) from these price
agreements. As of September 30, 1999, the Company had remaining price
agreements outstanding through March 2000 for 4.0 billion cubic feet of natural
gas production with an average Houston ship channel floor price of $1.93 per Mcf
and an average ceiling price of $2.38 per Mcf.
INTEREST RATE RISK
Total debt at September 30, 1999 included $179 million of floating-rate debt
attributed to the Term Loans and $337 million of fixed-rate debt. As a result,
the Company's annual interest cost will fluctuate based on short-term interest
rates. Based on the $179 million of outstanding floating-rate debt, the impact
on annual cash flow of a 10% change in the floating rate (approximately 71 basis
points) would be approximately $1.3 million.
At September 30, 1999, the fair market value of the Company's fixed-rate debt
approximated its book value of $337 million. The floating-rate debt will mature
over varying periods through 2003. Fixed-rate debt of $297 million will mature
in 2008, while other fixed-rate notes and obligations will mature over varying
periods through 2013.
28
<PAGE>
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
Exchange Act of 1934, as amended (the "Exchange Act"). These forward-looking
statements include, among other things, discussions of estimated revenue
enhancements and cost savings following the acquisitions in 1998, 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. 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, 1998, 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 that occur, or which the Company becomes aware of, after the date
hereof.
29
<PAGE>
PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
On September 16, 1999, the U.S. Environmental Protection Agency, Region IX
("USEPA") issued a letter to the Company's subsidiary, Tesoro Hawaii
Corporation ("Tesoro Hawaii"), alleging certain violations at Tesoro
Hawaii's refinery of facility response plan ("FRP") regulations under the
Clean Water Act. The USEPA alleges the refinery failed to revise its FRP to
include certain material changes at the facility; to resubmit the revisions
for agency approval in a timely manner; and, as a result, to properly
implement its FRP. The USEPA proposed a civil penalty assessment of
$99,600. The parties subsequently reached tentative agreement to resolve
all of the allegations for $39,500. Pending finalization of a consent
decree and payment of the settlement sum, the Company believes the
resolution of this matter will not have a material adverse effect on the
Company.
As previously reported, on October 19, 1998, the Company received notice
from the Environmental Protection Agency ("EPA") that it had been
identified as a potentially responsible party ("PRP") under the
Comprehensive Environmental Response, Compensation and Liability Act
("CERCLA") at the Casmalia Disposal Site ("Site") in Santa Barbara County,
California. The Site is being remediated by the EPA pursuant to CERCLA
Superfund law and the Resource Conservation and Recovery Act ("RCRA").
Although CERCLA imposes joint and several liability upon each party at the
Site, the extent of the Company's allocated financial contribution for
cleanup is expected to be de minimis based upon the number of companies,
volumes of waste involved, and total estimated cost to close the Site. On
October 12, 1999, the Company received a revised settlement offer from the
EPA to resolve the Company's liability at the Site for $80,000.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
(a) The 1999 Annual Meeting of Stockholders of the Company was held on
September 15, 1999.
(b) The following directors were elected at the 1999 Annual Meeting of
Stockholders to hold office until the 2000 Annual Meeting of
Stockholders or until their successors are elected and qualified. A
tabulation of the number of votes for or withheld with respect to each
such director is set forth below:
Votes
Name For Withheld
---- ----- --------
Steven H. Grapstein 28,726,206 85,372
William J. Johnson 28,728,505 83,073
Raymond K. Mason, Sr. 28,727,793 83,785
Donald H. Schmude 28,724,176 87,402
Bruce A. Smith 28,729,089 82,489
Patrick J. Ward 28,727,805 83,773
Murray L. Weidenbaum 28,722,292 89,286
Mr. Donald H. Schmude fills the vacancy created by the resignation of
Dr. Alan H. Kaufman, who resigned effective August 1, 1999.
(c) With respect to the ratification of the appointment of Deloitte &
Touche LLP as the Company's independent auditors for fiscal year 1999,
there were 28,757,224 votes for: 29,652 votes against; 24,702
abstentions; and no broker non-votes.
30
<PAGE>
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
27.1 Financial Data Schedule (September 30, 1999).
(b) Reports on Form 8-K
No reports on Form 8-K have been filed during the quarter for which
this report is filed.
31
<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: November 10, 1999 /s/ BRUCE A. SMITH
Bruce A. Smith
Chairman of the Board of Directors,
President and Chief Executive Officer
Date: November 10, 1999 /s/ DON M. HEEP
Don M. Heep
Vice President, Controller
(Chief Accounting Officer)
32
<PAGE>
EXHIBIT INDEX
Exhibit
Number
- -------
27.1 Financial Data Schedule (September 30, 1999).
33
<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 NINE MONTH
PERIOD ENDED SEPTEMBER 30, 1999 AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO
SUCH FINANCIAL STATEMENTS.
</LEGEND>
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 9-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-END> SEP-30-1999
<CASH> 15,600
<SECURITIES> 0
<RECEIVABLES> 246,300
<ALLOWANCES> 1,700
<INVENTORY> 197,700
<CURRENT-ASSETS> 468,500
<PP&E> 1,434,900
<DEPRECIATION> 496,600
<TOTAL-ASSETS> 1,557,300
<CURRENT-LIABILITIES> 306,100
<BONDS> 491,000
0
165,000
<COMMON> 5,400
<OTHER-SE> 438,800
<TOTAL-LIABILITY-AND-EQUITY> 1,557,300
<SALES> 2,174,700
<TOTAL-REVENUES> 2,175,700
<CGS> 1,963,900
<TOTAL-COSTS> 1,963,900
<OTHER-EXPENSES> 52,200
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 36,500
<INCOME-PRETAX> 95,400
<INCOME-TAX> 37,300
<INCOME-CONTINUING> 58,100
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 58,100
<EPS-BASIC> 1.52
<EPS-DILUTED> 1.35
<FN>
</TABLE>
