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Filed Pursuant to Rule 424(b)(3)
Registration No. 333-59871
PROSPECTUS
TESORO PETROLEUM CORPORATION
OFFER TO EXCHANGE
$1,000 PRINCIPAL AMOUNT OF 9% SENIOR SUBORDINATED NOTES DUE 2008, SERIES B
FOR EACH $1,000 PRINCIPAL AMOUNT OF OUTSTANDING
9% SENIOR SUBORDINATED NOTES DUE 2008
($300,000,000 IN AGGREGATE PRINCIPAL AMOUNT OUTSTANDING)
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THE EXCHANGE OFFER WILL EXPIRE AT 5:00 P.M.,
NEW YORK CITY TIME, ON SEPTEMBER 11, 1998, UNLESS EXTENDED
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Tesoro Petroleum Corporation, a Delaware corporation (the "Company"),
hereby offers, upon the terms and subject to the conditions set forth in this
Prospectus and the accompanying Letter of Transmittal, to exchange $1,000
principal amount of its 9% Senior Subordinated Notes due 2008, Series B (the
"Exchange Notes"), in a transaction registered under the Securities Act of 1933,
as amended (the "Securities Act"), pursuant to a Registration Statement (as
defined herein) of which this Prospectus constitutes a part, for each $1,000
principal amount of the outstanding 9% Senior Subordinated Notes due 2008 (the
"Old Notes"), of which $300,000,000 aggregate principal amount is outstanding
(the "Exchange Offer"). The Exchange Notes and the Old Notes are sometimes
referred to herein collectively as the "Notes."
The Company will accept for exchange any and all Old Notes that are validly
tendered and not withdrawn prior to 5:00 p.m., New York City time, on the date
the Exchange Offer expires, which will be September 11, 1998 unless the Exchange
Offer is extended (the "Expiration Date"). Tenders of Old Notes may be withdrawn
at any time prior to 5:00 p.m., New York City time, on the Expiration Date. The
Exchange Offer is not conditioned upon any minimum principal amount of Old Notes
being tendered for exchange. However, the Exchange Offer is subject to certain
conditions that may be waived by the Company and to the terms and provisions of
the Registration Rights Agreement (as defined herein). See "The Exchange Offer."
Old Notes may be tendered only in denominations of $1,000 and integral multiples
thereof. The Company has agreed to pay the expenses of the Exchange Offer. There
will be no cash proceeds to the Company from the Exchange Offer. See "Use of
Proceeds."
The Exchange Notes will be obligations of the Company entitled to the
benefits of the indenture relating to the Notes (the "Indenture"). The form and
terms of the Exchange Notes are identical in all material respects to the form
and terms of the Old Notes, except that (i) the offering of the Exchange Notes
has been registered under the Securities Act, (ii) the Exchange Notes will not
be subject to transfer restrictions and (iii) the Exchange Notes will not be
entitled to registration or other rights under the Registration Rights
Agreement, including the provision in the Registration Rights Agreement for
payment of Liquidated Damages (as defined in the Registration Rights Agreement)
upon either the failure by the Company to consummate the Exchange Offer or the
occurrence of certain other events. Following the Exchange Offer, any holders of
Old Notes will continue to be subject to the existing restrictions on transfer
thereof and, as a general matter, the Company will not have any further
obligation to such holders to provide for registration under the Securities Act
of transfers of the Old Notes held by such holders. To the extent that Old Notes
are tendered and accepted in the Exchange Offer, a holder's ability to sell
untendered and tendered but unaccepted Old Notes could be adversely affected.
See "Risk Factors" and "The Exchange Offer -- Purpose and Effect of the Exchange
Offer."
(continued on next page)
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SEE "RISK FACTORS" BEGINNING ON PAGE 19 FOR A DISCUSSION OF CERTAIN FACTORS
WHICH INVESTORS SHOULD CONSIDER IN CONNECTION WITH THE EXCHANGE OFFER AND AN
INVESTMENT IN THE EXCHANGE NOTES OFFERED HEREBY.
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THESE SECURITIES HAVE NOT BEEN APPROVED OR DISAPPROVED BY THE SECURITIES
AND EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION NOR HAS THE
SECURITIES AND EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION PASSED
UPON THE ACCURACY OR ADEQUACY OF THIS PROSPECTUS. ANY REPRESENTATION TO THE
CONTRARY IS A CRIMINAL OFFENSE.
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The date of this Prospectus is August 7, 1998.
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The Old Notes were sold by the Company on July 2, 1998, to Lehman Brothers
Inc., Bear, Stearns & Co. Inc. and Salomon Brothers Inc. (the "Initial
Purchasers") in transactions not registered under the Securities Act in reliance
upon the exemption provided in Section 4(2) of the Securities Act (the "Notes
Offering"). The Initial Purchasers placed the Old Notes with qualified
institutional buyers (as defined in Rule 144A under the Securities Act)
("Qualified Institutional Buyers" or "QIBs"), each of whom agreed to comply with
certain transfer restrictions and other restrictions. Accordingly, the Old Notes
may not be reoffered, resold or otherwise transferred in the United States
unless such transaction is registered under the Securities Act or an applicable
exemption from the registration requirements of the Securities Act is available.
The Exchange Notes are being offered hereby in order to satisfy the obligations
of the Company under a registration rights agreement among the Company and the
Initial Purchasers relating to the Old Notes (the "Registration Rights
Agreement").
The Exchange Notes will bear interest at a rate of 9% per annum, payable
semiannually on January 1 and July 1 of each year, commencing January 1, 1999.
Holders of Exchange Notes of record on December 15, 1998, will receive on
January 1, 1999, an interest payment in an amount equal to (x) the accrued
interest on such Exchange Notes from the date of issuance thereof to January 1,
1999, plus (y) the accrued interest on the previously held Old Notes from the
date of issuance of such Old Notes (July 2, 1998) to the date of exchange
thereof. The Notes mature on July 1, 2008.
The Old Notes were initially represented by three global Old Notes (the
"Old Global Notes") in registered form, registered in the name of Cede & Co., as
nominee for The Depository Trust Company ("DTC" or the "Depositary"), as
depositary. The Exchange Notes exchanged for Old Notes represented by the Old
Global Notes will be initially represented by two global Exchange Notes (the
"Exchange Global Notes") in registered form, registered in the name of the
Depositary. See "Description of the Notes -- Book-Entry; Delivery and Form."
References herein to "Global Notes" shall be references to the Old Global Notes
and the Exchange Global Notes.
Based on an interpretation of the Securities Act by the staff of the
Securities and Exchange Commission (the "SEC" or "Commission"), Exchange Notes
issued pursuant to the Exchange Offer in exchange for Old Notes may be offered
for resale, resold and otherwise transferred by a holder thereof (other than (i)
a broker-dealer who purchased such Old Notes directly from the Company for
resale pursuant to Rule 144A or any other available exemption under the
Securities Act or (ii) a person that is an "affiliate" (within the meaning of
Rule 405 of the Securities Act) of the Company), without compliance with the
registration and prospectus delivery provisions of the Securities Act, provided
that such holder is acquiring the Exchange Notes in its ordinary course of
business and is not participating, and has no arrangement or understanding with
any person to participate, in the distribution of the Exchange Notes. Holders of
Old Notes wishing to accept the Exchange Offer must represent to the Company
that such conditions have been met.
Each broker-dealer that receives Exchange Notes for its own account
pursuant to the Exchange Offer must agree that it will deliver a prospectus in
connection with any resale of such Exchange Notes. The Letter of Transmittal
states that by so acknowledging and by delivering a prospectus, a broker-dealer
will not be deemed to admit that it is an "underwriter" within the meaning of
the Securities Act. This Prospectus, as it may be amended or supplemented from
time to time, may be used by a broker-dealer in connection with resales of
Exchange Notes received in exchange for Old Notes where such Old Notes were
acquired by such broker-dealer as a result of market-making activities or other
trading activities. The Company has agreed that, for a period of one year after
the Expiration Date, it will make this Prospectus available to any broker-dealer
for use in connection with any such resale. See "Plan of Distribution."
The Exchange Notes will be a new issue of securities for which there
currently is no market. Although one of the Initial Purchasers has informed the
Company that it currently intends to make a market in the Exchange Notes, it is
not obligated to do so, and any such market making may be discontinued at any
time without notice. As the Old Notes were issued and the Exchange Notes are
being issued to a limited number of institutions who typically hold similar
securities for investment, the Company does not expect that an active public
market for the Exchange Notes will develop. Accordingly, there can be no
assurance as to the
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development, liquidity or maintenance of any market for the Exchange Notes on
any securities exchange or for quotation through the Nasdaq Stock Market. See
"Risk Factors."
NO DEALER, SALESPERSON OR OTHER INDIVIDUAL HAS BEEN AUTHORIZED TO GIVE ANY
INFORMATION OR TO MAKE ANY REPRESENTATIONS NOT CONTAINED IN THIS PROSPECTUS IN
CONNECTION WITH THE EXCHANGE OFFER COVERED BY THIS PROSPECTUS. IF GIVEN OR MADE,
SUCH INFORMATION OR REPRESENTATIONS MUST NOT BE RELIED UPON AS HAVING BEEN
AUTHORIZED BY THE COMPANY. THIS PROSPECTUS DOES NOT CONSTITUTE AN OFFER TO SELL,
OR A SOLICITATION OF AN OFFER TO BUY, THE EXCHANGE NOTES IN ANY JURISDICTION
WHERE, OR TO ANY PERSON TO WHOM, IT IS UNLAWFUL TO MAKE SUCH OFFER OR
SOLICITATION. NEITHER THE DELIVERY OF THIS PROSPECTUS NOR ANY SALE MADE
HEREUNDER SHALL, UNDER ANY CIRCUMSTANCES, CREATE ANY IMPLICATIONS THAT THERE HAS
NOT BEEN ANY CHANGE IN THE FACTS SET FORTH IN THIS PROSPECTUS OR IN THE AFFAIRS
OF THE COMPANY SINCE THE DATE HEREOF.
NOTICE TO NEW HAMPSHIRE RESIDENTS
NEITHER THE FACT THAT A REGISTRATION STATEMENT OR AN APPLICATION FOR A
LICENSE HAS BEEN FILED WITH THE STATE OF NEW HAMPSHIRE NOR THE FACT THAT A
SECURITY IS EFFECTIVELY REGISTERED OR A PERSON IS LICENSED IN THE STATE OF NEW
HAMPSHIRE CONSTITUTES A FINDING BY THE SECRETARY OF STATE THAT ANY DOCUMENT
FILED UNDER RSA 421-B IS TRUE, COMPLETE AND NOT MISLEADING. NEITHER ANY SUCH
FACT NOR THE FACT THAT AN EXEMPTION OR EXCEPTION IS AVAILABLE FOR A SECURITY OR
A TRANSACTION MEANS THAT THE SECRETARY OF STATE HAS PASSED IN ANY WAY UPON THE
MERITS OR QUALIFICATIONS OF, OR RECOMMENDED OR GIVEN APPROVAL TO, ANY PERSON,
SECURITY, OR TRANSACTION. IT IS UNLAWFUL TO MAKE, OR CAUSE TO BE MADE, TO ANY
PROSPECTIVE PURCHASER, CUSTOMER, OR CLIENT ANY REPRESENTATION INCONSISTENT WITH
THE PROVISIONS OF THIS PARAGRAPH.
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PROSPECTUS SUMMARY
The following summary is qualified in its entirety by and should be read in
conjunction with the detailed information and financial statements and notes
thereto appearing elsewhere in this Prospectus. Prospective investors should
carefully consider the matters discussed under the caption "Risk Factors."
Except as the context otherwise requires, information in this Prospectus assumes
that (i) the Hawaii Acquisition (as defined herein), (ii) the Washington
Acquisition (as defined herein), (iii) the initial borrowings under the Senior
Credit Facility (as defined herein), (iv) the Notes Offering (as defined
herein), (v) the PIES Offering (as defined herein), (vi) the Common Stock
Offering (as defined herein) and (vii) the exercise of the underwriters'
over-allotment options granted in connection with the PIES Offering and Common
Stock Offering (collectively, the "Transactions") have been consummated. All
such transactions have actually been consummated except for the Washington
Acquisition. AS USED IN THIS PROSPECTUS, THE TERM "TESORO" REFERS TO TESORO
PETROLEUM CORPORATION BEFORE THE TRANSACTIONS, AND THE TERM "COMPANY" REFERS TO
TESORO PETROLEUM CORPORATION PRO FORMA FOR THE TRANSACTIONS. The information
contained in this Prospectus with respect to BHP Hawaii (as defined herein) and
Shell Washington (as defined herein) has been supplied to Tesoro by BHP (as
defined herein) and Shell (as defined herein), respectively.
THE COMPANY
OVERVIEW
The Company is a diversified natural resource company with operations in
three business segments: (i) refining crude oil and marketing petroleum products
("Refining and Marketing"), (ii) exploration for, and development and production
of primarily natural gas ("Exploration and Production") and (iii) marketing and
distributing petroleum products and providing logistics services to the marine
and offshore exploration and production industries ("Marine Services"). Tesoro
has demonstrated consistent growth in each of these segments over the past three
years. Tesoro's Normalized EBITDA (as defined herein) has increased from $50.0
million in 1995 to $98.2 million in 1997. Pro forma for the Transactions, the
Company generated Normalized EBITDA of $178.6 million for the year ended
December 31, 1997 (excluding potential cost savings and revenue enhancements
anticipated to result from the Acquisitions (as defined herein)), with 65%
attributable to Refining and Marketing, 32% attributable to Exploration and
Production and 3% attributable to Marine Services.
REFINING AND MARKETING
The Company is the second largest independent refiner and marketer of
petroleum products in the Petroleum Administration for Defense District V ("PADD
V"), a federal regional designation encompassing Alaska, Arizona, California,
Hawaii, Nevada, Oregon and Washington. The Company owns and operates three major
West Coast refineries located in: Kenai, Alaska (the "Alaska Refinery"), on the
eastern side of the Cook Inlet; Kapolei, Hawaii (the "Hawaii Refinery"), on the
island of Oahu; and Anacortes, Washington (the "Washington Refinery"), on the
Puget Sound approximately 60 miles north of Seattle. The Alaska Refinery has a
rated capacity of 72,000 barrels per day ("bpd") and is the second largest
refinery in Alaska. The Hawaii Refinery has a rated capacity of 95,000 bpd and
is the largest refinery in Hawaii. The Washington Refinery has a rated capacity
of 108,000 bpd and is the third largest refinery in the Pacific Northwest. The
Company is also a major retailer of gasoline in Alaska and Hawaii and is
continuing to build a retail presence in the Pacific Northwest. As of March 31,
1998, the Company had 160 branded retail stations in Alaska (35 Company owned
and operated), 32 branded retail stations in Hawaii (30 Company owned and
operated) and 33 branded retail stations in the Pacific Northwest.
ALASKA. The Alaskan market is geographically isolated, making
transportation and terminaling costs a significant competitive factor. The
nearest competitive alternative markets to Alaska are Canada and the U.S.
Pacific Northwest. The transportation costs involved to move refined products
between these markets and Alaska are significant, which results in the Company
receiving higher margins on its refined products that are
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sold in the local Alaskan market. During 1997, approximately 70% of the refined
product volumes manufactured at the Alaska Refinery were sold within the local
Alaskan market.
Over the last three years, Tesoro has significantly increased its in-state
sales of refined products in Alaska, which have generated substantial
improvements in its Alaska refining and marketing operating results. Tesoro has
accomplished this goal through a combination of (i) capital improvements and
feedstock alterations at its Alaska Refinery that allow the refinery to
manufacture a product slate that is more in line with local market demands, and
(ii) an expansion of its in-state marketing channels for gasoline, heavy oils
and other refined products. As a result of these and other initiatives, Tesoro's
in-state sales of refined products manufactured at the Alaska Refinery have
increased by over 4,500 bpd from 1995 to 1997. Over this same time period, the
Alaska Refinery's product spread has increased from approximately $3.44 per
barrel to $5.09 per barrel and Tesoro's Alaska refining and marketing Normalized
EBITDA has increased from $13 million to $33 million.
Recent major capital improvements to the Alaska Refinery include the
construction of a vacuum unit in late 1994 for approximately $25 million and the
expansion of the hydrocracker unit in late 1997 for approximately $19 million,
which included the introduction of a jet selective catalyst. As a result of
these two refinery upgrades, the Company has significantly increased its
production of jet fuel, which is currently in short supply in Alaska, and
reduced its production of lower margin residual fuel oil and other heavy oils.
The majority of these heavy oils must be exported to markets outside of Alaska
due to the current level of local demand. Prior to these major capital
improvements, the Alaska Refinery's product mix was approximately 37% middle
distillates (primarily jet fuel and diesel fuel), 24% gasoline, and 39% residual
fuel and other heavy oils on total production of 51,100 bpd in 1993, versus a
product mix during the first quarter of 1998 of 44% middle distillates, 26%
gasoline and 30% residual fuel oil and other heavy oils on total production of
57,700 bpd.
The Company also has expanded and enhanced its Alaska retail gasoline
network by converting third-party stations to "Tesoro Alaska" branded stations,
building and acquiring stations, remodeling existing profitable stations and
closing underperforming stations. In the last three years, the number of branded
stations selling Company gasoline in Alaska has increased from 131 to 160. The
Company plans to add additional branded retail stations in 1998 as a part of its
three-year, $50 million Alaskan retail expansion program. Additionally, Tesoro
improved its product spread by beginning to manufacture and market liquid
asphalt in Alaska in 1996. Due to this change in product slate and the
completion of an asphalt terminal in Anchorage, Alaska, sales of liquid asphalt
sold in-state by Tesoro tripled from 1996 to 1997.
HAWAII. The Company's Alaskan operations and its recently acquired Hawaii
operations have many similar characteristics. Both markets are geographically
isolated, making transportation and terminaling costs a significant competitive
factor. Both markets have a small number of local refiners. The Company operates
one of two major refineries in Alaska and the larger of two refineries in
Hawaii. Both markets have similar supply and demand characteristics for most
refined products. Middle distillates account for the largest percentage of total
refined product demand. In-state demand for middle distillates is currently
higher than in-state production and in-state demand for gasoline and heavy oils
is currently lower than in-state production. With these similar market dynamics,
both the Alaska and Hawaii Refineries are configured to maximize production of
middle distillates. Both refineries process similar grades of crude oil and
yield similar refined product slates. Due to the strong similarities between the
Alaska and Hawaii Refineries and the corresponding local markets, the Company
believes there will be significant opportunities to improve the performance of
the Hawaii Refinery by applying some of the same techniques the Company has used
in Alaska.
WASHINGTON. The Washington Acquisition gives the Company a major refining
presence in the Pacific Northwest, an area in which Tesoro has been an active
marketer of refined products since the 1980s. Tesoro currently markets gasoline
(through 33 dealer-operated branded retail stations and one terminal), bunker
fuels and other heavy oil products in the Pacific Northwest. BHP Hawaii also
currently markets certain excess refined products in the Pacific Northwest.
The Company believes that the Pacific Northwest is one of the most
attractive U.S. refining markets. Washington and Oregon are currently ranked as
the sixth and tenth fastest growing states in the U.S., respectively. Population
growth in Washington and Oregon averaged 11% for the five-year period ending
1995.
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Gasoline production in the Pacific Northwest is currently slightly higher than
local demand. Due to strong projected demand growth, however, the Company
believes that the gasoline market will be in balance or slightly short within
two to three years.
The Washington Refinery is a relatively complex refinery that produces a
large percentage of gasoline and other high value products. During 1997, the
Washington Refinery's product mix was approximately 53% gasoline, 24% middle
distillates and 23% heavy oils and other. Additionally, the Washington Refinery
can produce significant amounts of CARB gasoline, a gasoline formulation
required in the California market which reduces vehicle emissions.
The Company believes that there are significant cost saving and revenue
enhancement opportunities available through integrating its Washington Refinery
with its Alaska and Hawaii Refineries. The Tesoro management team has currently
identified $25 million of potential annual cost saving and revenue enhancing
synergies including improvements to administrative and logistical efficiencies,
further processing of intermediate products and other marketing and operating
benefits. Management expects to begin to realize such synergies in the fourth
quarter of 1998 with the full annual impact to be achieved in the fiscal year
ending December 31, 1999. In addition, the Company believes that there will be
incremental opportunities, which have not yet been identified, from owning three
refineries in PADD V.
EXPLORATION AND PRODUCTION
The Company is engaged in the exploration for and acquisition, development
and exploitation of primarily natural gas properties in Texas, Louisiana and
Bolivia. As of December 31, 1997, the Company had over 517 billion cubic feet
equivalent ("Bcfe") of proved reserves, 93% of which are natural gas, with a
standardized measure of discounted future net cash flows before income taxes
utilizing a 10% discount rate ("Pre-Tax PV10") of approximately $374 million.
Approximately 30% of the Company's proved reserves and 45% of the Company's
Pre-Tax PV10 are attributable to its U.S. properties.
The Company has a demonstrated track record of finding, developing and
producing oil and gas reserves at a relatively low cost. Over the last five
years, the Company has more than doubled worldwide proved reserves at an average
finding and development cost of approximately $0.52 per thousand cubic feet
equivalent ("Mcfe"). The Company has increased production from approximately 62
million cubic feet equivalents ("MMcfe") per day in 1993 to 109 MMcfe per day in
1997 and was producing approximately 130 MMcfe per day during March 1998. During
1997, the Company increased its domestic proved reserves by 28% and its Bolivian
proved reserves by 45% at a worldwide average finding cost of $0.49 per Mcfe.
The Company believes it is well positioned to further increase its proved
reserves and production in both the U.S. and Bolivia.
In the U.S., Tesoro has assembled a substantial inventory of new
exploration and development prospects. In the last year, the Company almost
tripled its net undeveloped acreage to in excess of 130,000 acres. The Company
is positioned in four core areas: the Val Verde Basin in Southwest Texas, the
Wilcox Trend in South Texas, the Frio/Vicksburg Trend along the U.S. Gulf Coast
and the East Texas Basin. During 1997, the Company's U.S. exploration efforts
resulted in commercial discoveries in three of these core areas. As a result of
these new discoveries, the Company has added a significant inventory of lower
risk development drilling opportunities for 1998.
In Bolivia, a significant portion of the Company's proved developed
reserves are currently shut-in due to limited access to markets. However, during
1997, construction began on a 1,900-mile Bolivia-to-Brazil natural gas pipeline
which the Company believes will significantly increase the market for Bolivian
gas production. The pipeline, which is jointly owned by Enron Corp., Shell
International Gas Ltd. and Petroleo Brasileiro S.A. (known as Petrobras, the
Brazilian state oil company), among others, is expected to be completed by early
1999. Upon completion of the pipeline, the Company believes that it will be able
to increase its Bolivian natural gas production. See "Business -- Exploration
and Production -- Overview." Tesoro's Bolivian production during 1997 averaged
37 MMcfe per day (gross), and the Company estimates that it could currently
produce from its existing proved developed reserve base approximately 120 MMcfe
per day (gross) if access to markets were readily available. The Company's 1998
capital budget includes plans to drill three development wells (gross) and two
exploratory wells (gross) which may increase its productive capacity.
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MARINE SERVICES
Tesoro is the largest operator of marine terminals along the Texas and
Louisiana Gulf Coast and is building a presence on the U.S. West Coast. The
Company currently operates 20 marine terminals in Texas and Louisiana and three
terminals on the U.S. West Coast. Through its terminal facilities, the Company
markets and distributes a broad range of products, including diesel fuel,
lubricants, chemicals and supplies, and provides logistical support services to
the marine and offshore exploration and production industries. The marine
terminals are generally deep water and are bulkheaded and dredged to provide
easy access to vessels receiving products for delivery to customers. Products
are also delivered offshore aboard vessels owned or chartered by customers,
which include companies engaged in oil and gas exploration and production,
seismic evaluation, offshore construction and other drilling-related businesses.
The acquisition of Coastwide Energy Services, Inc. ("Coastwide") in 1996
plus recent facility improvements and cost reduction initiatives have
significantly enhanced the Company's competitive position and operating results
in the marine services industry. The Company's Normalized EBITDA attributable to
its Marine Services segment has increased from a negative $3.3 million in 1995
to a positive $8.0 million in 1997. The marine services industry remains
fragmented. The Company believes that there are significant consolidation
opportunities in this sector as well as additional optimization opportunities
relating to its existing operations that will allow it to continue to profitably
grow this business segment.
STRATEGY AND COMPETITIVE STRENGTHS
The Company's strategy is to (i) maximize return on capital employed and
increase the competitiveness of each of its business units by reducing costs,
increasing operating efficiencies and optimizing existing assets and (ii) expand
its overall market presence through a combination of internal growth initiatives
and selective acquisitions which are both accretive to earnings and provide
significant operational synergies.
The Company believes that it is well positioned to execute its strategy as
a result of the following competitive strengths:
STRONG POSITION IN NICHE MARKETS. In Refining and Marketing, the Company
operates the largest refinery in Hawaii, the second largest refinery in Alaska
and will operate the third largest refinery in Washington. The Company is also a
major retailer of gasoline in Alaska and Hawaii and is enhancing its retail
presence in the Pacific Northwest. In Exploration and Production, the Company
has demonstrated a track record of finding, developing and producing oil and gas
reserves at relatively low costs compared to others in the industry. In Marine
Services, the Company is the largest operator of marine terminals along the
Texas and Louisiana Gulf Coast.
DIVERSIFIED CASH FLOW BASE. Pro forma for the Transactions, for the year
ended December 31, 1997, the Company generated approximately 65% of its
Normalized EBITDA from its Refining and Marketing segment, 32% from its
Exploration and Production segment and 3% from its Marine Services segment
(excluding potential cost savings and revenue enhancement opportunities).
Furthermore, pro forma Normalized EBITDA from the Refining and Marketing segment
would be distributed among its three areas of operations. The diversity of the
Company's assets and successful operation of its three business segments reduce
the Company's dependence on any one area of the natural resources industry,
which subsequently reduces the volatility of the Company's earnings and
Normalized EBITDA.
STRONG TRACK RECORD. Over the last four years, Tesoro has made significant
operating improvements in each of its business segments. From 1993 to 1997,
Tesoro's Normalized EBITDA increased from approximately $35 million to $98
million. During this same time period, Tesoro reduced its total debt and
preferred stock outstanding from $264 million to approximately $132 million.
EXPERIENCED MANAGEMENT TEAM. The Company benefits from a strong and
experienced management team at both the corporate and the operating levels.
Tesoro's senior management team has an average 25 years of experience in the oil
and gas industry. The Company's management team has successfully restructured
each of its operating segments and significantly improved its operating and
financial performance over the last five years.
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THE TRANSACTIONS
THE ACQUISITIONS
THE HAWAII ACQUISITION. On May 29, 1998, Tesoro closed the acquisition (the
"Hawaii Acquisition") of all of the outstanding capital stock of BHP Petroleum
Americas Refining Inc. and BHP Petroleum South Pacific Inc. (together, "BHP
Hawaii"), both of which were affiliates of The Broken Hill Proprietary Company
Limited ("BHP"). BHP Hawaii owned and operated a 95,000 bpd refinery in Kapolei,
Hawaii, on the island of Oahu, approximately 20 miles west of Honolulu, and 32
retail gasoline stations (two of which are dealer-operated) on Oahu, Maui and
Hawaii.
The cash purchase price for the Hawaii Acquisition was $243.5 million. In
addition, Tesoro issued an unsecured, non-interest bearing promissory note (the
"BHP Note") in the amount of $50 million, payable in five equal annual
installments, beginning in 2009. The BHP Note provides for earlier payment based
on the performance of BHP Hawaii. The purchase price is subject to adjustment
after the closing for the amount by which the working capital of BHP Hawaii on
the closing date differs from $68.5 million, the estimated working capital at
closing. See "Description of Other Indebtedness -- Other Indebtedness."
In order to ensure the continuity of crude supply to the Hawaii Refinery,
the Company also entered into a two-year agreement with an affiliate of BHP to
assist Tesoro in acquiring crude oil feedstock sourced outside of North America
and in arranging for transportation of such crude oil to the Hawaii Refinery.
See "Business -- Refining and Marketing -- Crude Oil Supply -- Hawaii."
THE WASHINGTON ACQUISITION. On May 1, 1998, Tesoro entered into an
agreement (the "Washington Agreement") to purchase (the "Washington
Acquisition," and together with the Hawaii Acquisition, the "Acquisitions") all
of the outstanding capital stock of Shell Anacortes Refining Company ("Shell
Washington"), an affiliate of Shell Oil Company ("Shell"). Shell Washington owns
and operates a 108,000 bpd refinery (the "Washington Refinery") located in
Anacortes, Washington (on the Puget Sound, approximately 60 miles north of
Seattle) and related assets.
Under the terms of the Washington Agreement, the Company has agreed to pay
at closing a purchase price of $237 million plus estimated working capital as of
closing. The Company has made a $5 million earnest money deposit and has
escrowed $266.9 million for the purchase price of Shell Washington. Based on the
March 31, 1998 balance sheet, the Company estimates that the working capital to
be acquired is approximately $43 million. The Washington Agreement contains
representations and warranties and other general provisions that are customary
for transactions of this nature.
Shell is selling Shell Washington pursuant to agreements with the U.S.
Federal Trade Commission (the "FTC") and the states of Oregon and Washington
resulting from its western states refining and marketing joint venture with
Texaco. The closing of the Washington Acquisition is contingent upon the
approval of the FTC and the states of Oregon and Washington and other customary
conditions. Tesoro currently anticipates that the Washington Acquisition will
close on or after August 1, 1998.
THE FINANCING
THE INTERIM CREDIT FACILITY. In conjunction with closing the Hawaii
Acquisition, Tesoro refinanced substantially all of its then-existing
indebtedness (the "Refinancing"). The total amount of funds required by Tesoro
to complete the Hawaii Acquisition and the Refinancing, to pay related fees and
expenses and for general corporate purposes was approximately $432 million,
which was financed through a secured credit facility (the "Interim Credit
Facility") provided by Lehman Commercial Paper Inc. ("LCPI"), an affiliate of
Lehman Brothers Inc. The Company refinanced all borrowings under the Interim
Credit Facility with net proceeds from the Offerings (as defined below), and
borrowings under the Senior Credit Facility (as defined below).
THE SENIOR CREDIT FACILITY. On July 2, 1998, and in connection with the
Notes Offering and the Washington Acquisition, the Company entered into a new
senior credit facility (the "Senior Credit Facility") in the amount of $500
million. The Senior Credit Facility is comprised of term loan facilities
aggregating
5
<PAGE> 9
$200 million (two $100 million tranches, the "Tranche A Term Loans" and the
"Tranche B Term Loan") and a $300 million revolving credit facility (the
"Revolver"). The Senior Credit Facility is guaranteed by substantially all of
the Company's active direct and indirect subsidiaries (the "Guarantors") and is
secured by substantially all of the domestic assets of the Company and each of
the Guarantors. See "Description of Other Indebtedness -- Senior Credit
Facility."
THE OFFERINGS. On July 2, 1998, concurrently with the syndication of the
Senior Credit Facility, the Company issued $300 million aggregate principal
amount of the Old Notes (the "Notes Offering"). On July 1, 1998, the Company
issued 9,000,000 PIES (the "PIES Offering"), representing interests in the
Company's Mandatorily Convertible Preferred Stock, with gross proceeds of $143.4
million and 5,000,000 shares of Common Stock, with gross proceeds of $79.7
million (the "Common Stock Offering," and together with the Notes Offering and
the PIES Offering, the "Offerings"). Upon exercise of the over-allotment options
granted to the underwriters of the Common Stock Offering and PIES Offering, the
Company issued 1,350,000 PIES with gross proceeds of $21.5 million and 750,000
shares of Common Stock with gross proceeds of $11.9 million. See "Description of
the Notes" and "Description of Capital Stock."
Borrowings under the Senior Credit Facility, together with the net proceeds
from the Offerings, were used to fund the cash purchase price of the Washington
Acquisition, to refinance the Interim Credit Facility (a portion of which was
used to finance the Hawaii Acquisition), to pay certain fees and expenses
related to the Transactions and for general corporate purposes (including
working capital requirements and capital expenditures).
6
<PAGE> 10
SUMMARY OF TERMS OF EXCHANGE OFFER
The Exchange Offer relates to the exchange of up to $300,000,000 aggregate
principal amount of Exchange Notes for up to an equal aggregate principal amount
of Old Notes. The Exchange Notes will be obligations of the Company entitled to
the benefits of the Indenture. The form and terms of the Exchange Notes are
identical in all material respects to the form and terms of the Old Notes,
except that (i) the offering of the Exchange Notes has been registered under the
Securities Act, (ii) the Exchange Notes will not be subject to transfer
restrictions and (iii) the Exchange Notes will not be entitled to registration
or other rights under the Registration Rights Agreement including the provision
in the Registration Rights Agreement for payment of Liquidated Damages upon
failure by the Company to consummate the Exchange Offer or the occurrence of
certain other events. See "Description of the Notes." Capitalized terms followed
by the parenthetical "(as defined)" and not defined herein will have the
meanings given them in the Indenture.
Registration Rights
Agreement.................. The Old Notes were sold by the Company on July 2,
1998 to the Initial Purchasers pursuant to a
Purchase Agreement, dated June 29, 1998 (the
"Purchase Agreement"). Pursuant to the Purchase
Agreement, the Company and the Initial Purchasers
entered into the Registration Rights Agreement
which, among other things, grants the holders of
the Old Notes certain exchange and registration
rights. The Exchange Offer is intended to satisfy
certain obligations of the Company under the
Registration Rights Agreement.
The Exchange Offer......... $1,000 principal amount of Exchange Notes will be
issued in exchange for each $1,000 principal amount
of Old Notes validly tendered and accepted pursuant
to the Exchange Offer. As of the date hereof,
$300,000,000 in aggregate principal amount of Old
Notes are outstanding. The Company will issue the
Exchange Notes to tendering holders of Old Notes
promptly following the Expiration Date. The terms
of the Exchange Notes are identical in all material
respects to the Old Notes except for certain
transfer restrictions and registration rights
relating to the Old Notes.
No federal or state regulatory requirements must be
complied with or approval obtained in connection
with the Exchange Offer, other than the
registration requirements under the Securities Act.
Resale..................... Based on existing interpretations of the Securities
Act by the staff of the SEC set forth in several
no-action letters to third parties, and subject to
the immediately following sentence, the Company
believes that Exchange Notes issued pursuant to the
Exchange Offer in exchange for Old Notes may be
offered for resale, resold and otherwise
transferred by a holder thereof (other than (i) a
broker-dealer who purchased such Old Notes directly
from the Company for resale pursuant to Rule 144A
or any other available exemption under the
Securities Act or (ii) a person that is an
"affiliate" (within the meaning of Rule 405 of the
Securities Act) of the Company), without compliance
with the registration and prospectus delivery
provisions of the Securities Act, provided that the
holder is acquiring the Exchange Notes in its
ordinary course of business and is not
participating, and has no arrangement or
understanding with any person to participate, in
the distribution of the Exchange Notes. However,
any purchaser of Old Notes who is an affiliate of
the Company or who intends to participate in the
Exchange Offer for the purpose of distributing the
Exchange Notes, or any broker-dealer who purchased
the Old Notes from the Company to resell pursuant
to Rule 144A or any other available exemption under
the Securities Act, (i) will not be able
7
<PAGE> 11
to rely on the interpretations by the staff of the
SEC set forth in the above-mentioned no-action
letters, (ii) will not be able to tender its Old
Notes in the Exchange Offer and (iii) must comply
with the registration and prospectus delivery
requirements of the Securities Act in connection
with any sale or transfer of the Notes unless such
sale or transfer is made pursuant to an exemption
from such requirements. The Company does not intend
to seek its own no-action letter and there is no
assurance that the staff of the SEC would make a
similar determination with respect to the Exchange
Notes as it has in such no-action letters to third
parties. See "The Exchange Offer -- Purpose and
Effect of the Exchange Offer" and "Plan of
Distribution." Each broker-dealer that receives
Exchange Notes for its own account pursuant to the
Exchange Offer must acknowledge that it will
deliver a prospectus in connection with any resale
of such Exchange Notes. The Letter of Transmittal
states that by so acknowledging and by delivering a
prospectus, a broker-dealer will not be deemed to
admit that it is an "underwriter" within the
meaning of the Securities Act. This Prospectus, as
it may be amended or supplemented from time to
time, may be used by a broker-dealer in connection
with resales of Exchange Notes received in exchange
for Old Notes where such Old Notes were acquired by
such broker-dealer as a result of market-making
activities or other trading activities. The Company
has agreed that, for a period of one year after the
Expiration Date, it will make this Prospectus
available to any broker-dealer for use in
connection with any such resale. See "Plan of
Distribution."
Expiration Date............ 5:00 p.m., New York City time, on September 11,
1998, unless the Exchange Offer is extended, in
which case the term "Expiration Date" means the
latest date and time to which the Exchange Offer is
extended. See "The Exchange Offer -- Expiration
Date; Extensions; Amendments."
Accrued Interest on the
Exchange Notes and the
Old Notes................ The Exchange Notes will bear interest at a rate of
9% per annum, payable semiannually on January 1 and
July 1 of each year, commencing January 1, 1999.
Holders of Exchange Notes of record on December 15,
1998, will receive on January 1, 1999, an interest
payment in an amount equal to (i) the accrued
interest on such Exchange Notes from the date of
issuance thereof to January 1, 1999, plus (ii) the
accrued interest on the previously held Old Notes
from the date of issuance of such Old Notes (July
2, 1998) to the date of exchange thereof. The Notes
mature on July 1, 2008.
Conditions to the Exchange
Offer.................... The Company may terminate the Exchange Offer if it
determines that its ability to proceed with the
Exchange Offer could be materially impaired due to
the occurrence of certain conditions. The Company
does not expect any of such conditions to occur,
although there can be no assurance that such
conditions will not occur. Holders of Old Notes
will have certain rights under the Registration
Rights Agreement should the Company fail to
consummate the Exchange Offer. See "The Exchange
Offer -- Conditions to the Exchange Offer" and
"Description of the Notes -- Registration Rights;
Liquidated Damages."
8
<PAGE> 12
Procedures for Tendering
Old Notes.................. Each holder of Old Notes wishing to accept the
Exchange Offer must complete, sign and date the
Letter of Transmittal, or a facsimile thereof, in
accordance with the instructions contained herein
and therein, and mail or otherwise deliver such
Letter of Transmittal, or such facsimile, together
with the Old Notes to be exchanged and any other
required documentation, to U.S. Bank Trust National
Association, as Exchange Agent, at the address set
forth herein and therein or effect a tender of Old
Notes pursuant to the procedures for book-entry
transfer as provided for herein and therein. By
executing the Letter of Transmittal, each holder
will represent to the Company that, among other
things, the Exchange Notes acquired pursuant to the
Exchange Offer are being acquired in the ordinary
course of business of the person receiving such
Exchange Notes, whether or not such person is the
holder, that neither the holder nor any such other
person has any arrangement or understanding with
any person to participate in the distribution of
such Exchange Notes and that neither the holder nor
any such other person is an "affiliate," as defined
in Rule 405 under the Securities Act, of the
Company. See "The Exchange Offer -- Procedures for
Tendering."
Following consummation of the Exchange Offer,
holders of Old Notes not tendered as a general
matter will not have any further registration
rights, and the Old Notes will continue to be
subject to certain restrictions on transfer.
Accordingly, the liquidity of the market for the
Old Notes could be adversely affected. See "Risk
Factors -- Absence of Public Market for the Notes"
and "Risk Factors -- Consequences of Exchange and
Failure to Exchange" and "The Exchange Offer --
Consequences of Failure to Exchange."
Special Procedures for
Beneficial Owners.......... Any beneficial owner whose Old Notes are registered
in the name of a broker, dealer, commercial bank,
trust company or other nominee and who wishes to
tender in the Exchange Offer should contact such
registered holder promptly and instruct such
registered holder to tender on his behalf. If such
beneficial owner wishes to tender on his own
behalf, such beneficial owner must, prior to
completing and executing the Letter of Transmittal
and delivering his Old Notes, either (a) make
appropriate arrangements to register ownership of
the Old Notes in such holder's name or (b) obtain a
properly completed bond power from the registered
holder or endorsed certificates representing the
Old Notes to be tendered. The transfer of record
ownership may take considerable time, and
completion of such transfer prior to the Expiration
Date may not be possible. See "The Exchange
Offer -- Procedures for Tendering."
Guaranteed Delivery
Procedures............... Holders of Old Notes who wish to tender their Old
Notes and whose Old Notes are not immediately
available, or who cannot deliver their Old Notes
(or complete the procedure for book-entry transfer)
and deliver a properly completed Letter of
Transmittal and any other documents required by the
Letter of Transmittal to the Exchange Agent prior
to the Expiration Date may tender their Old Notes
according to the guaranteed delivery procedures set
forth in "The Exchange Offer -- Guaranteed Delivery
Procedures."
9
<PAGE> 13
Withdrawal Rights.......... Tenders of Old Notes may be withdrawn at any time
prior to the Expiration Date by furnishing a
written or facsimile transmission notice of
withdrawal to the Exchange Agent containing the
information set forth in "The Exchange
Offer -- Withdrawal of Tenders."
Acceptance of Old Notes and
Delivery of Exchange
Notes.................... Subject to certain conditions (as summarized above
in "Conditions to the Exchange Offer" and described
more fully in "The Exchange Offer -- Expiration
Date; Extensions; Amendments"), the Company will
accept for exchange any and all Old Notes that are
properly tendered in the Exchange Offer prior to
the Expiration Date. See "The Exchange
Offer -- Procedures for Tendering." The Exchange
Notes issued pursuant to the Exchange Offer will be
delivered promptly following the Expiration Date.
Exchange Agent............. U.S. Bank Trust National Association, the Trustee
under the Indenture, is serving as exchange agent
(the "Exchange Agent") in connection with the
Exchange Offer. The registered, certified or
overnight mail or courier address of the Exchange
Agent is U.S. Bank Trust N.A., 180 East Fifth
Street, St. Paul, MN 55101, Attention: Specialized
Finance, SPFT0414. The hand delivery address for
the Exchange Agent is U.S. Bank Trust N.A., 4th
Floor Bond Drop Window, 180 East Fifth Street, St.
Paul, MN 55101, and the first class mail address is
U.S. Bank Trust N.A., P.O. Box 64485, St. Paul, MN
55164-9549. For assistance and request for
additional copies of this Prospectus, the Letter of
Transmittal or the Notice of Guaranteed Delivery,
the telephone number for the Exchange Agent is
(651) 244-1197, and the facsimile number for the
Exchange Agent is (612) 244-1537 (Eligible
Institutions only). All communications should be
directed to the attention of Kevin Gorman.
Effect on Holders of Old
Notes.................... Holders of Old Notes who do not tender their Old
Notes in the Exchange Offer will continue to hold
their Old Notes and will be entitled to all the
rights and limitations applicable thereto under the
Indenture. All untendered, and tendered but
unaccepted, Old Notes will continue to be subject
to the restrictions on transfer provided for in the
Old Notes and the Indenture. To the extent that Old
Notes are tendered and accepted in the Exchange
Offer, the trading market, if any, for the Old
Notes could be adversely affected. See "Risk
Factors -- Consequences of Exchange and Failure to
Exchange."
See "The Exchange Offer" for more detailed information concerning the terms of
the Exchange Offer.
10
<PAGE> 14
SUMMARY OF TERMS OF EXCHANGE NOTES
Securities................. $300,000,000 aggregate principal amount of 9%
Senior Subordinated Notes due 2008, Series B.
Maturity................... July 1, 2008
Interest Payment Dates..... Interest on the Notes will be payable semiannually
in arrears on January 1 and July 1 of each year,
commencing January 1, 1999.
Mandatory Redemption....... Except as set forth below under Special Redemption,
the Company will not be required to make mandatory
redemption or sinking fund payments with respect to
the Exchange Notes.
Optional Redemption........ The Exchange Notes will be redeemable at the option
of the Company, in whole or in part, at any time on
or after July 1, 2003, at the redemption prices set
forth herein, plus accrued and unpaid interest, if
any, thereon to the date of redemption. In
addition, at any time on or prior to July 1, 2001,
the Company may, at its option, redeem up to 35% of
the aggregate principal amount of the Notes
outstanding at a redemption price equal to 109% of
the principal amount thereof, plus accrued and
unpaid interest, if any, thereon to the date of
redemption, with the net cash proceeds of one or
more Public Equity Offerings (as defined herein);
provided that at least 65% of the aggregate
principal amount of Notes issued in the Notes
Offering remain outstanding immediately after each
such redemption. See "Description of the
Notes -- Optional Redemption."
Special Redemption......... If the Washington Acquisition is not consummated,
or the related acquisition agreement is terminated
before such consummation, on or prior to December
31, 1998, the Company will be required to redeem
50% of the aggregate principal amount of the Notes
issued in the Notes Offering on the earlier of
December 31, 1998 and ten business days following
termination of the acquisition agreement (the
"Special Redemption Date") at a price equal to 101%
of the redeemed principal amount thereof (the
"Special Redemption Price"), plus accrued and
unpaid interest, if any, to the Special Redemption
Date. The Company deposited $266.9 million into an
escrow account created pursuant to the Washington
Agreement to secure payment of the purchase price
for the Washington Acquisition. It is expected that
in the event the Washington Acquisition is not
consummated (without fault of the Company), such
escrowed funds will be available to fund payment of
the Special Redemption Price. See "Use of Proceeds"
and "Description of the Notes -- Special
Redemption."
Change of Control.......... Upon the occurrence of a Change of Control, each
holder of the Exchange Notes will have the right to
require the Company to repurchase all or any part
of such Holder's Exchange Notes at a price equal to
101% of the principal amount thereof, plus accrued
and unpaid interest, if any, thereon to the date of
repurchase. See "Risk Factors -- Potential
Inability to Fund a Change of Control Offer" and
"Description of the Notes -- Repurchase at the
Option of Holders -- Change of Control."
Ranking.................... The Exchange Notes will be general unsecured
obligations of the Company subordinate in right of
payment to all existing and future Senior Debt of
the Company and the Guarantors, including
borrowings under the Senior Credit Facility, and
senior in right of payment to, or pari passu with,
all other present or future indebtedness of the
Company.
11
<PAGE> 15
As of March 31, 1998, after giving pro forma effect
to the Transactions, the Company and the Guarantors
would have had approximately $185.2 million of
Senior Debt outstanding (exclusive of an additional
$350.0 million available under the Senior Credit
Facility, which, if drawn, would be Senior Debt).
The Indenture will permit the Company and its
subsidiaries to incur additional indebtedness,
including additional Senior Debt, subject to
certain conditions. See "Description of the
Notes -- Subordination" and "Capitalization."
Subsidiary Guarantees...... The Company's payment obligations under the
Exchange Notes are jointly and severally guaranteed
on a senior subordinated basis (the "Subsidiary
Guarantees") by the Guarantors, which constitute
substantially all of the Company's active
subsidiaries. The Subsidiary Guarantees will be
subordinate in right of payment to all existing and
future Senior Debt of the Guarantors, including the
Guarantors' guarantees of the Company's obligations
under the Senior Credit Facility. See "Description
of the Notes -- Subsidiary Guarantees."
Certain Covenants.......... The Indenture contains certain covenants that,
among other things, restrict the ability of the
Company and its Restricted Subsidiaries (as defined
herein) to: (i) incur additional indebtedness and
issue preferred stock; (ii) pay dividends or make
certain other restricted payments; (iii) enter into
transactions with affiliates; (iv) make certain
asset dispositions; (v) merge or consolidate with,
or transfer substantially all of its assets to,
another Person (as defined herein); (vi) encumber
assets under certain circumstances; (vii) restrict
dividends and other payments from Restricted
Subsidiaries; (viii) issue Capital Stock (as
defined herein) of Wholly Owned Restricted
Subsidiaries (as defined herein); or (ix) engage in
certain business activities. See "Description of
the Notes -- Certain Covenants." In addition, under
certain circumstances, the Company will be required
to offer to repurchase the Exchange Notes at a
price equal to 100% of the aggregate principal
amount thereof, plus accrued and unpaid interest,
if any, thereon to the date of repurchase, with the
excess proceeds of certain Asset Sales (as defined
herein). See "Description of the
Notes -- Repurchase at the Option of
Holders -- Asset Sales."
FOR A DISCUSSION OF CERTAIN FACTORS THAT SHOULD BE CONSIDERED IN CONNECTION
WITH AN INVESTMENT IN THE EXCHANGE NOTES, SEE "RISK FACTORS."
12
<PAGE> 16
SUMMARY HISTORICAL AND PRO FORMA FINANCIAL DATA
The following tables set forth certain summary historical condensed
consolidated financial data for Tesoro and certain historical pro forma
information for the Company. The summary historical financial information
presented below for each of the three years ended December 31, 1997, and for
each of the quarters ended March 31, 1997 and 1998, has been derived from the
financial statements included elsewhere herein. The pro forma statements of
consolidated operations for the year ended December 31, 1997, and the pro forma
statement of consolidated operations for the three months ended March 31, 1998,
give effect to the Transactions as if all had occurred on January 1, 1997. The
pro forma balance sheet gives effect to the Transactions as if all had occurred
on March 31, 1998. The unaudited pro forma information set forth below is not
necessarily indicative of the results that actually would have been achieved had
such Transactions been consummated on January 1, 1997, or that may be achieved
in the future. The unaudited pro forma financial statements do not reflect any
benefits from potential cost savings or revenue enhancements resulting from the
integration of the operations of Tesoro, BHP Hawaii and Shell Washington
(estimated by the Company to be $25 million annually beginning in 1999). The
information should be read in conjunction with the Management's Discussion and
Analysis of Financial Condition and Results of Operations, the Selected
Historical Financial Data, the Pro Forma Combined Condensed Statements of
Operations and the Pro Forma Financial Statements of Tesoro, BHP Hawaii and
Shell Washington and the notes thereto included herein.
<TABLE>
<CAPTION>
THREE MONTHS ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
---------------------------------------- ---------------------------
1997 1998
1995 1996 1997 PRO FORMA 1997 1998 PRO FORMA
-------- -------- ------ --------- ------ ------ ---------
(IN MILLIONS EXCEPT PER SHARE AMOUNTS AND RATIOS)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENTS OF OPERATIONS DATA:
Total revenues(a)......................... $1,002.9 $1,039.8 $943.4 $2,980.4 $234.9 $196.0 $ 607.9
Total segment operating profit(a)(b)...... $ 105.9 $ 144.8 $ 72.7 $ 163.1 $ 15.0 $ 17.9 $ 34.7
Earnings before extraordinary items....... $ 57.5 $ 76.8 $ 30.7 $ 31.9 $ 6.1 $ 6.1 $ 4.9
OTHER DATA:
EBITDA(c):
Refining and marketing.................. $ 12.6 $ 18.5 $ 33.2 $ 148.4 $ 3.2 $ 9.5 $ 32.5
Exploration and production.............. 139.2 159.6 77.2 77.2 22.1 19.0 19.0
Marine services......................... (4.1) 7.3 8.0 8.0 1.3 2.4 2.4
-------- -------- ------ -------- ------ ------ --------
Total segment EBITDA.................. 147.7 185.4 118.4 233.6 26.6 30.9 53.9
Corporate and unallocated............... (22.3) (13.4) (16.2) (55.0) (3.7) (4.1) (11.6)
-------- -------- ------ -------- ------ ------ --------
Total consolidated EBITDA............. $ 125.4 $ 172.0 $102.2 $ 178.6(e) $ 22.9 $ 26.8 $ 42.3(e)
======== ======== ====== ======== ====== ====== ========
Normalized EBITDA(d):
Refining and marketing.................. $ 13.0 $ 19.3 $ 33.2 $ 148.4 $ 3.2 $ 9.5 $ 32.5
Exploration and production.............. 58.8 70.0 73.2 73.2 20.5 19.0 19.0
Marine services......................... (3.3) 7.3 8.0 8.0 1.3 2.4 2.4
-------- -------- ------ -------- ------ ------ --------
Total segment Normalized EBITDA....... 68.5 96.6 114.4 229.6 25.0 30.9 53.9
Corporate and unallocated............... (18.5) (14.7) (16.2) (51.0) (3.7) (4.1) (11.6)
-------- -------- ------ -------- ------ ------ --------
Total consolidated Normalized
EBITDA.............................. $ 50.0 $ 81.9 $ 98.2 $ 178.6(e) $ 21.3 $ 26.8 $ 42.3(e)
======== ======== ====== ======== ====== ====== ========
Total Debt/Normalized EBITDA.............. * 3.03(f)
Normalized EBITDA/Interest Expense(d)..... 3.40 3.17
Normalized EBITDA/Interest plus Preferred
Dividends............................... 2.76 2.60
Capital expenditures
Refining and marketing.................. $ 9.3 $ 11.1 $ 43.9 * $ 2.9 $ 2.0 *
Exploration and production.............. 53.4 66.6 92.9 * 11.0 20.5 *
Marine services......................... 0.4 6.9 9.4 * 2.2 1.2 *
Other................................... 0.8 0.4 1.3 * 0.2 0.1 *
-------- -------- ------ ------ ------
Total capital expenditures........ $ 63.9 $ 85.0 $147.5 * $ 16.3 $ 23.8 *
======== ======== ====== ====== ======
BALANCE SHEET DATA:
Working capital........................... $ 77.5 $ 99.5 $ 74.3 * $104.8 $ 86.7 $ 202.7
Property, plant and equipment, net........ $ 261.7 $ 316.5 $413.8 * $320.7 $424.4 $ 924.4
Total assets.............................. $ 519.2 $ 582.6 $627.8 * $552.0 $635.4 $1,398.9
Total long-term debt and other
obligations............................. $ 164.5 $ 89.3 $132.3 * $ 89.3 $147.7 $ 483.5
Stockholders' equity...................... $ 216.5 $ 304.1 $333.0 * $310.4 $339.4 $ 580.3
</TABLE>
- ---------------
* Not available.
(a) Results for the years 1995 and 1996 include revenues from above-market
pricing provisions of a natural gas contract which was terminated effective
October 1, 1996. Operating profit included $47 million and $25 million in
the years 1995 and 1996, respectively, from the excess of these contract
prices over spot market prices. Upon termination of the contract in 1996,
the Exploration and Production segment also recorded a non-recurring
increase in other income and operating profit of $60 million in connection
with the settlement of the contract. In the year 1995, the Exploration
13
<PAGE> 17
and Production segment recorded other income and operating profit of $33
million from the sale of certain interests in the Bob West Field. See Notes
C and D of Notes to Tesoro's Consolidated Financial Statements.
(b) Segment operating profit equals gross operating revenues, gains and losses
on asset sales and other income less applicable segment costs of sales,
operating expenses, depreciation, depletion and other items. Income taxes,
interest expense and corporate general and administrative expenses are not
included in determining operating profit.
(c) EBITDA represents earnings before extraordinary item, interest expense,
income taxes and depreciation, depletion and amortization. Segment EBITDA
represents operating profit before 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.
EBITDA is not a calculation based upon generally accepted accounting
principles ("GAAP"); however, the amounts included in the EBITDA
calculation are derived from amounts included in Tesoro's Consolidated
Financial Statements. In addition, EBITDA should not be considered as an
alternative to net earnings or operating profit, as an indication of the
operating performance of the Company or an alternative to operating cash
flow as a measure of liquidity. EBITDA is not necessarily comparable to
similarly titled items of other companies.
(d) Normalized EBITDA is EBITDA, as defined in (c) above, excluding the impact
of the above-market natural gas contract with Tennessee Gas (as defined
herein) and other significant items which affect the comparability between
the periods presented. The following items have been excluded from EBITDA,
as reported, to generate normalized EBITDA for each segment (in millions):
<TABLE>
<CAPTION>
THREE MONTHS
ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
------------------------------------ ------------------------
1997 1998
1995 1996 1997 PRO FORMA 1997 1998 PRO FORMA
----- ----- ---- --------- ---- ---- ---------
<S> <C> <C> <C> <C> <C> <C> <C>
Refining and Marketing.......... $(0.4) $(0.8) $-- $ -- $-- $-- $ --
----- ----- ---- ----- ---- ---- ----
Exploration and Production:
Excess of contract prices over
spot market prices.......... 47.1 24.6 -- -- -- -- --
Income from settlement of a
natural gas contract........ -- 60.0 -- -- -- -- --
Gain on sale of asset......... 33.5 -- -- -- -- -- --
Other non-recurring income
(charges), net.............. (0.2) 5.0 4.0 4.0 1.6 -- --
----- ----- ---- ----- ---- ---- ----
Total Exploration and
Production........... 80.4 89.6 4.0 4.0 1.6 -- --
----- ----- ---- ----- ---- ---- ----
Marine Services................. (0.8) -- -- -- -- -- --
----- ----- ---- ----- ---- ---- ----
Corporate and Unallocated....... (3.8) 1.3 -- (4.0)(i) -- -- --
----- ----- ---- ----- ---- ---- ----
Total Adjustments...... $75.4 $90.1 $4.0 $ -- $1.6 $-- $ --
===== ===== ==== ===== ==== ==== ====
</TABLE>
(i) Represents BHP Hawaii employee bonuses of $4 million which were
awarded based upon the performance of BHP operations that are not to
be acquired by Tesoro.
For further information regarding these significant items, see "Management's
Discussion and Analysis of Financial Condition and Results of Operations."
(e) Pro forma EBITDA represents earnings before extraordinary items plus
interest expense, income taxes, depreciation, depletion and amortization,
and amortization of financing costs, all on a pro forma basis.
(f) Normalized EBITDA for the three-month period has been annualized to
calculate this ratio.
14
<PAGE> 18
SUMMARY REFINING AND MARKETING OPERATING DATA
<TABLE>
<CAPTION>
THREE MONTHS
FISCAL YEARS(A) ENDED
-------------------------- MARCH 31,
1995 1996 1997 1998
------ ------ ------ ------------
<S> <C> <C> <C> <C>
REFINERY THROUGHPUT (thousands of bpd)
Alaska Refinery.................................. 50.6 47.5 50.2 56.1
Hawaii Refinery.................................. 90.6 86.7 88.7 86.4
Washington Refinery.............................. 104.9 114.5 113.0 114.6
------ ------ ------ ------
Total Throughput......................... 246.1 248.7 251.9 257.1
====== ====== ====== ======
REFINED PRODUCTS MANUFACTURED (thousands of bpd)
Alaska Refinery --
Gasoline and gasoline blendstocks............. 14.3 12.8 12.8 15.2
Middle distillates, including jet fuel and
diesel fuel................................. 20.7 20.0 21.6 25.2
Heavy oils and residual products.............. 14.5 13.7 14.8 15.1
Other......................................... 2.5 2.6 2.3 2.2
------ ------ ------ ------
Total Alaska Refinery.................... 52.0 49.1 51.5 57.7
------ ------ ------ ------
Hawaii Refinery --
Gasoline and gasoline blendstocks............. 22.1 19.0 22.0 19.8
Middle distillates, including jet fuel and
diesel fuel................................. 39.3 39.6 40.4 40.3
Heavy oils and residual products.............. 27.1 25.9 24.3 23.4
Other......................................... 3.2 2.6 2.9 3.5
------ ------ ------ ------
Total Hawaii Refinery.................... 91.7 87.1 89.6 87.0
------ ------ ------ ------
Washington Refinery --
Gasoline and gasoline blendstocks............. 60.3 64.2 62.1 63.2
Middle distillates, including jet fuel and
diesel fuel................................. 24.1 28.9 28.3 29.9
Heavy oils and residual products.............. 14.9 15.3 17.1 16.2
Other......................................... 9.6 10.4 9.9 10.0
------ ------ ------ ------
Total Washington Refinery................ 108.9 118.8 117.4 119.3
------ ------ ------ ------
Total Refined Products Manufactured...... 252.6 255.0 258.5 264.0
====== ====== ====== ======
REFINERY PRODUCT SPREAD ($/barrel)
Alaska Refinery(b)............................... $ 3.44 $ 4.29 $ 5.09 $ 4.75
Hawaii Refinery(c)............................... $ 5.53 $ 5.48 $ 5.45 $ 4.00
Washington Refinery(b)........................... $ 3.63 $ 3.63 $ 2.89 $ 1.07
NUMBER OF STATIONS SELLING THE REFINERIES'
GASOLINE(d)
Alaska --
Company-operated.............................. 32 33 35 35
Branded jobbers and dealers................... 99 126 129 125
Unbranded jobbers and dealers................. 28 29 28 25
Pacific Northwest -- branded jobbers and
dealers....................................... 10 18 30 33
Hawaii -- Company-operated....................... 28 28 28 30
Hawaii -- Dealer-operated........................ 1 2 2 2
------ ------ ------ ------
Total Stations........................... 198 236 252 250
====== ====== ====== ======
</TABLE>
- ---------------
(a) Amounts for Tesoro and Shell Washington are for fiscal years ended December
31. Amounts for BHP Hawaii are for fiscal years ended May 31. Refining and
marketing data for the Hawaii Refinery and Washington Refinery have been
provided by BHP and Shell, respectively.
(b) Refinery product spread for the Alaska Refinery and Washington Refinery is
calculated as the per barrel difference between the average yield value of
refined products manufactured at the Alaska Refinery or
15
<PAGE> 19
Washington Refinery during the periods presented and the average cost to
manufacture these products. Refinery product spread does not take into
account adjustments due to selling a volume and mix of products that is
different than actual volumes manufactured during the periods. Refinery
product spread for the Alaska Refinery also does not take into account
margins on product purchased and resold.
(c) Refinery product spread for the Hawaii Refinery is calculated as the per
barrel difference between net sales of refined products manufactured and
the landed cost of crude oil processed on a FIFO inventory valuation
method. The calculation is based on sales volumes during the periods
presented and does not include manufacturing cost allocations or refined
products purchased and resold.
(d) Branded gasoline stations sell the Alaska Refinery's gasoline under the
"Tesoro Alaska" name in Alaska, Oregon and Washington (191 stations as of
March 31, 1998) and under the "Union 76" name in Southeast Alaska (two
stations as of March 31, 1998). Stations that sell the Company's gasoline
under a different name are considered unbranded. Branded gasoline stations
sell the Hawaii Refinery's gasoline under the "Gas Express" name in Hawaii.
As of March 31, 1998, the Company operated 38 convenience stores located in
Alaska, 35 of which sell gasoline.
16
<PAGE> 20
SUMMARY EXPLORATION AND PRODUCTION
RESERVE AND OPERATING DATA
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED
------------------------ MARCH 31,
1995 1996 1997 1998
------ ------ ------ ------------
<S> <C> <C> <C> <C>
NET PROVED RESERVES AT END OF PERIOD (BCFE)+
U.S. ................................................ 106.4 117.8 150.4 *
Bolivia.............................................. 98.0 253.0 366.4 *
------ ------ ------
Total........................................ 204.4 370.8 516.8 *
====== ====== ======
% Natural Gas........................................ 95% 94% 93% *
PRE-TAX PV10 AT END OF PERIOD ($ MILLIONS)
U.S. ................................................ $168.8 $222.7 $167.5 *
Bolivia.............................................. 48.7 133.8 206.5 *
------ ------ ------
Total........................................ $217.5 $356.5 $374.0 *
====== ====== ======
AVERAGE DAILY NET PRODUCTION (MMCFE)+
U.S. ................................................ 114.5 87.8 86.7 100.2
Bolivia.............................................. 22.1 23.8 22.7 27.6
------ ------ ------ ------
Total........................................ 136.6 111.6 109.4 127.8
====== ====== ====== ======
% Natural Gas........................................ 98% 97% 97% 95%
AVERAGE SALES PRICES
Natural gas ($/Mcf):
U.S. --
Spot market(a).................................. $ 1.34 $ 1.95 $ 2.17 $ 2.01
Average(b)...................................... $ 2.57 $ 2.75 $ 2.17 $ 2.01
Bolivia........................................... $ 1.28 $ 1.33 $ 1.15 $ 0.97
Oil and condensate ($/barrel) --
U.S. ............................................. $16.82 $21.99 $18.90 $14.13
Bolivia........................................... $14.39 $17.98 $15.71 $15.78
AVERAGE OPERATING EXPENSES ($/MCFE)+
U.S. ................................................ $ 0.35 $ 0.27 $ 0.30 $ 0.32
Bolivia.............................................. $ 0.48 $ 0.42 $ 0.42 $ 0.40
THREE-YEAR AVERAGE COSTS OF ADDING RESERVES ($/MCFE)(c)
U.S. ................................................ $ 0.70 $ 0.94 $ 0.85 *
Bolivia.............................................. $ 2.86 $ 0.09 $ 0.14 *
Total........................................ $ 0.74 $ 0.53 $ 0.43 *
</TABLE>
- ---------------
* Not available
+ Bcfe, MMcfe and Mcfe are based on the assumption that six Mcf of natural
gas is equal to one barrel of crude oil.
(a) Includes effects of the Company's natural gas commodity price agreements
which amounted to a gain of $0.01 per thousand cubic feet ("Mcf") in the
year 1995 and to losses of $0.11 per Mcf and $0.05 per Mcf in the years
1996 and 1997, respectively (see Note N of Notes to Tesoro's Consolidated
Financial Statements).
(b) Average natural gas sales prices for the years 1995 and 1996 include the
effect of above-market pricing provisions under the contract with Tennessee
Gas that terminated effective October 1, 1996 (see Note D of Notes to
Tesoro's Consolidated Financial Statements).
(c) Represents total capital costs for the three years ended 1995, 1996 and
1997, respectively, divided by total proved reserve additions for the same
periods. Total capital costs include exploration, development and property
acquisition costs. Total reserve additions include extensions, discoveries,
purchases of minerals in place and revisions of previous estimates.
17
<PAGE> 21
FORWARD-LOOKING STATEMENTS
This Prospectus contains certain statements that are "forward-looking"
statements within the meaning of Section 27A of the Securities Act of 1933, as
amended (the "Securities Act") and Section 21E of the Securities and Exchange
Act of 1934, as amended (the "Exchange Act"). All statements other than
statements of historical facts included in this Prospectus, including without
limitation statements that use terminology such as "anticipate," "believe,"
"continue," "estimate," "expect," "intend," "may," "plan," "predict," "should,"
"will" and similar expressions, are forward-looking statements. These
forward-looking statements include, among other things, discussions of
anticipated revenue enhancements and cost savings following the Acquisitions,
the Company's business strategy and expectations concerning the Company's market
position, future operations, margins, profitability, liquidity and capital
resources, expenditures for capital projects and attempts to reduce costs.
Although the Company believes that the assumptions upon which the
forward-looking statements contained in this Prospectus 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. Important factors that could cause actual results to differ
materially from the Company's expectations are set forth under the captions
"Summary," "Risk Factors," "Pro Forma Financial Statements," "Management's
Discussion and Analysis of Financial Condition and Results of Operations" and
"Business," and elsewhere in this Prospectus. Actual results and trends in the
future may differ materially depending on a variety of factors including, but
not limited to, the timing and extent of changes in commodity prices and
underlying demand and availability of crude oil and other refinery feedstocks,
refined products, and natural gas; changes in the cost or availability of
third-party vessels, pipelines and other means of transporting feedstocks and
products; execution of planned capital projects; adverse changes in the credit
ratings assigned to the Company's trade credit; future well performance; the
extent of the Company's success in acquiring oil and gas properties and in
discovering, developing and producing reserves; state and federal environmental,
economic, safety and other policies and regulations, any changes therein, and
any legal or regulatory delays or other factors beyond the Company's control;
adverse rulings, judgments, or settlements in litigation or other legal matters,
including unexpected environmental remediation costs in excess of any reserves;
actions of customers and competitors; weather conditions affecting the Company's
operations or the areas in which the Company's products are marketed;
earthquakes or other natural disasters affecting operations; political
developments in foreign countries; and the conditions of the capital markets and
equity markets during the periods covered by the forward-looking statements.
Future results will also be dependent upon the ability of the Company to
integrate the Acquisitions with the Company's other operations. Many of the
factors are described in greater detail in the Company's Annual Report on Form
10-K for the year ended December 31, 1997, and other of the Company's filings
with the Commission. All subsequent written and oral forward-looking statements
attributable to the Company or persons acting on its behalf are expressly
qualified in their entirety by the foregoing. The Company undertakes no
obligation to publicly release the result of any revisions to any such
forward-looking statements that may be made to reflect events or circumstances
after the date hereof or to reflect the occurrence of unanticipated events.
18
<PAGE> 22
RISK FACTORS
Holders of the Old Notes should carefully review the information contained
elsewhere in this Prospectus and should particularly consider the following
matters before tendering any Old Notes for exchange into Exchange Notes. See
"Forward-Looking Statements." Certain matters set forth below also apply to the
Old Notes and will continue to apply to the Old Notes remaining outstanding
after the Exchange Offer.
SUBSTANTIAL LEVERAGE AND DEBT SERVICE
In connection with the Transactions, the Company has incurred substantial
additional indebtedness with significant debt service requirements. Upon
issuance of the Old Notes in the Notes Offering, entering into the Senior Credit
Facility and the application of the estimated net proceeds therefrom, the
Company's pro forma consolidated indebtedness as of March 31, 1998, would have
been $483.5 million (including the Old Notes, but excluding an additional $350.0
million available for borrowings under the Senior Credit Facility). See
"Capitalization." The Company's high degree of leverage may have important
consequences including the following: (i) the ability of the Company to obtain
additional financing for capital expenditures, working capital, acquisitions or
other purposes, if necessary, may be impaired or such financing may not be on
terms favorable to the Company; (ii) a substantial portion of the Company's cash
flow will be used to make debt service payments, which will reduce the funds
that would otherwise be available to the Company for its operations and future
business opportunities; (iii) the Company's flexibility in planning for or
reacting to changes in market conditions may be limited; (iv) the Company may be
more vulnerable to the impact of a downturn in its business or the economy
generally; and (v) to the extent of the Company's outstanding debt under the
Senior Credit Facility, the Company will be vulnerable to the impact of an
increase in interest rates. See "Description of Other Indebtedness" and
"Description of Capital Stock -- Mandatorily Convertible Preferred Stock."
The Company's ability to make scheduled payments of principal of, or to pay
the interest on, or to refinance, its indebtedness (including the Notes), or to
fund planned capital expenditures, will depend upon its future performance,
which, in turn, is subject to general economic, financial, competitive,
legislative, regulatory and other factors that are beyond its control. Based
upon current levels of operations, the Company believes that its cash flow from
operations, amounts available under the Senior Credit Facility and available
cash will be adequate to meet its anticipated future requirements for working
capital, capital expenditures, scheduled payments of principal and interest on
its indebtedness, including the Notes, and preferred stock dividend payments.
There can be no assurance, however, that the Company's business will generate
cash flow at or above anticipated levels or that the Company will be able to
borrow funds under the Senior Credit Facility in an amount sufficient to enable
the Company to service its indebtedness, including the Notes, preferred stock
dividend payments or make anticipated capital expenditures. If the Company is
unable to generate sufficient cash flow from operations or to borrow sufficient
funds in the future to service its debt and to make its preferred stock dividend
payments, it may be required to sell assets, reduce capital expenditures,
refinance all or a portion of its existing debt (including the Notes) or obtain
additional financing. There can be no assurance that any such financing could be
obtained, particularly in view of the restrictions on the Company's ability to
incur additional debt under the Senior Credit Facility and the Indenture, and
the fact that substantially all of the Company's domestic assets have been
pledged to secure obligations under the Senior Credit Facility.
SUBORDINATION AND RANKING OF THE NOTES AND SUBSIDIARY GUARANTEES
The Notes and Subsidiary Guarantees are general unsecured obligations of
the Company, subordinate in right of payment to all existing and future Senior
Debt of the Company, including all indebtedness under the Senior Credit
Facility. The Senior Credit Facility is secured by liens upon substantially all
of the domestic assets of the Company and the Guarantors. By reason of such
subordination, in the event of insolvency, liquidation, reorganization,
dissolution or other winding-up of the Company or any Guarantor, the Senior Debt
of such Person must be paid in full before the principal of, and premium, if
any, and interest on the Notes may be paid. In the event of a bankruptcy,
liquidation or reorganization of the Company or any Guarantor, Holders of the
Notes will participate ratably with all holders of subordinated indebtedness of
the Company or any
19
<PAGE> 23
Guarantor that is deemed to be of the same class as the Notes, based upon
respective amounts owed to each holder or creditor, in the remaining assets of
the Company or any Guarantor. If any of the foregoing events should occur, there
can be no assurance that there would be sufficient assets to pay amounts due on
the Notes. In addition, the Indenture provides that no payment with respect to
the Notes may be made in the event of a payment default with respect to Senior
Debt under certain circumstances, and the holders of certain designated Senior
Debt, including indebtedness under the Senior Credit Facility, will be entitled
to preferred payments with respect to the Notes in the event of a nonpayment
default on such designated Senior Debt. The Indenture permits the Company to
incur additional indebtedness under certain conditions. See "Capitalization,"
"Description of Other Indebtedness" and "Description of the Notes -- Certain
Covenants."
HOLDING COMPANY STRUCTURE
The Company is a holding company that conducts substantially all of its
operations through subsidiaries. The Company's only significant assets are the
capital stock of its wholly owned subsidiaries. As a holding company, the
Company is dependent on distributions of funds from its subsidiaries to meet the
Company's debt service, preferred stock dividend and payment and other
obligations, including the payment of principal and interest on the Notes. The
Notes are unsecured senior subordinated obligations of the Company and, as such,
are subordinated to the Company's obligations under the Senior Credit Facility
and all other existing and future Senior Debt of the Company with respect to the
payment of principal, premium, if any, and interest. The holders of the Notes
are effectively subordinated to claims of creditors of the subsidiaries other
than Guarantors, including trade creditors of, and banks and other lenders to,
such subsidiaries. See "Description of the Notes -- Subordination."
CONSEQUENCES OF FAILURE TO CLOSE WASHINGTON ACQUISITION
If the Washington Acquisition is not consummated, or the Washington
Agreement is terminated before such consummation, on or prior to December 31,
1998, the Company will be required to redeem 50% of the aggregate principal
amount of the Notes at the Special Redemption Price, plus accrued and unpaid
interest and Liquidated Damages, if any, to the Special Redemption Date. If the
Washington Acquisition is not consummated, the Company's assets, operations,
capital and expected financial results will be substantially different from
those set forth herein on a pro forma basis. The outstanding indebtedness of the
Company would be reduced as a result of the failure to consummate the Washington
Acquisition and the subsequent special redemption of the Notes. See
"Capitalization," "Pro Forma Financial Statements" and "Description of the
Notes -- Special Redemption."
RESTRICTIVE DEBT COVENANTS
The Indenture contains covenants that restrict, among other things, the
ability of the Company to incur additional indebtedness, pay dividends or make
certain other Restricted Payments, enter into transactions with affiliates, make
certain asset dispositions, merge or consolidate with, or transfer substantially
all of its assets to another Person, encumber assets under certain
circumstances, restrict dividends and other payments from Restricted
Subsidiaries, issue capital stock of Wholly Owned Restricted Subsidiaries,
engage in certain business activities, or engage in certain change of control
transactions. In addition, the Senior Credit Facility contains other and more
restrictive covenants and prohibits the Company from voluntary or optional
prepayments of certain of its indebtedness, including the Notes. Under the
Senior Credit Facility, the Company is also required to comply with specified
financial covenants, including a maximum ratio of total debt to EBITDA and a
minimum interest coverage ratio. The failure by the Company to comply with such
financial covenants or to comply with the restrictions contained in the Senior
Credit Facility or the Indenture could result in a default thereunder, which in
turn could cause such indebtedness (and by reason of cross-default provisions,
other indebtedness) to become immediately due and payable. The Company's ability
to comply with such covenants can be affected by many events beyond its control
and no assurance can be given that the Company's future operating results will
be sufficient to enable compliance with such covenants, or in the event of a
default, to remedy such default. See "Description of Other Indebtedness."
20
<PAGE> 24
FRAUDULENT CONVEYANCE CONSIDERATIONS RELATING TO SUBSIDIARY GUARANTEES
The Company's obligations under the Notes are guaranteed on a general
unsecured basis by the Guarantors (as defined herein). Various preference or
fraudulent conveyance laws have been enacted for the protection of creditors and
may be utilized by a court of competent jurisdiction to subordinate or avoid any
Subsidiary Guarantee issued by a Guarantor. It is also possible that under
certain circumstances a court could hold that the direct obligations of a
Guarantor could be superior to the obligations under the Subsidiary Guarantee.
See "Description of the Notes -- Subsidiary Guarantees."
To the extent that a court were to find that at the time a Guarantor
entered into a Subsidiary Guarantee either (x) the Subsidiary Guarantee was
incurred by a Guarantor with the intent to hinder, delay or defraud any present
or future creditor or that a Guarantor contemplated insolvency with a design to
favor one or more creditors to the exclusion in whole or in part of others or
(y) the Guarantor did not receive fair consideration or reasonably equivalent
value for issuing the Subsidiary Guarantee and, at the time it issued the
Subsidiary Guarantee, the Guarantor (i) was insolvent or rendered insolvent by
reason of the issuance of the Subsidiary Guarantee, (ii) was engaged or about to
engage in a business or transaction for which the remaining assets of the
Guarantor constituted unreasonably small capital or (iii) intended to incur, or
believed that it would incur, debts beyond its ability to pay such debts as they
matured, the court could avoid or subordinate the Subsidiary Guarantee in favor
of the Guarantor's other creditors. Among other things, a legal challenge of a
Subsidiary Guarantee issued by a Guarantor on fraudulent conveyance grounds may
focus on the benefits, if any, realized by the Guarantor as a result of the
issuance by the Company of the Old Notes. To the extent a Subsidiary Guarantee
is avoided as a fraudulent conveyance or held unenforceable for any other
reason, the holders of the Notes would cease to have any claim in respect of
such Guarantor and would be creditors solely of the Company.
On the basis of the financial information or other information currently
available to it, the Company believes that the Old Notes and the Subsidiary
Guarantees issued concurrently with the issuance of the Old Notes were incurred
for proper purposes and in good faith and that, after giving effect to
indebtedness incurred in connection with entering into the Senior Credit
Facility, the issuance of the Old Notes and the issuance of the Subsidiary
Guarantees, the Company and the Guarantors are solvent and will continue to be
solvent, will have sufficient capital for carrying on their respective
businesses and will be able to pay their debts as such debts become absolute and
mature. There can be no assurance, however, that a court passing on such
questions would reach the same conclusions.
POTENTIAL INABILITY TO FUND A CHANGE OF CONTROL OFFER
In the event of a Change of Control (as defined in the Indenture), each
Holder will have the right to require the Company to repurchase all or any
portion of its Notes then outstanding at a purchase price equal to 101% of the
principal amount thereof, plus accrued and unpaid interest and Liquidated
Damages, if any, thereon, to the date of repurchase. See "Description of the
Notes -- Repurchase at the Option of Holders -- Change of Control."
The events that constitute a Change of Control under the Indenture may also
be events of default under other indebtedness of the Company. Such events may
prohibit the Company from repurchasing the Notes, permit the lenders under such
debt instruments to accelerate the debt and, if the debt is not paid, to enforce
security interests on, or commence litigation that could ultimately result in a
sale of, substantially all the assets of the Company. If the Company is unable
to repay all of such indebtedness or is unable to obtain any necessary consents,
then the Company will be unable to offer to repurchase the Notes and such
failure will constitute an Event of Default under the Indenture. There can be no
assurance that the Company will have sufficient funds available at the time of
any Change of Control to make any debt payment (including repurchases of Notes)
as described above. See "Description of Other Indebtedness."
ABSENCE OF PUBLIC MARKET FOR THE NOTES
The Old Notes are currently owned by a relatively small number of
beneficial owners. The Old Notes have not been registered under the Securities
Act or any state securities laws and, unless so registered and to
21
<PAGE> 25
the extent not exchanged for the Exchange Notes, may not be offered or sold
except pursuant to an exemption from, or in a transaction not subject to, the
registration requirements of the Securities Act and applicable state securities
laws. Any Old Notes tendered and exchanged in the Exchange Offer will reduce the
aggregate principal amount of Old Notes outstanding. Following the consummation
of the Exchange Offer, holders who did not tender their Old Notes generally will
not have any further registration rights under the Registration Rights
Agreement, and such Old Notes will continue to be subject to certain
restrictions on transfer. Accordingly, the liquidity of the market for such Old
Notes could be adversely affected. The Old Notes are currently eligible for sale
pursuant to Rule 144A through The Portal Market of the National Association of
Securities Dealers, Inc. ("Portal"). Because the Company anticipates that most
holders will elect to exchange their Old Notes for Exchange Notes due to the
restrictions on the resale of Old Notes under the Securities Act, the Company
anticipates that the liquidity of the market for any Old Notes remaining after
the consummation of the Exchange Offer may be substantially limited.
The Exchange Notes will constitute a new issue of securities for which
there is currently no active trading market. If the Exchange Notes are traded
after their initial issuance, they may trade at a discount from their initial
offering price, depending upon prevailing interest rates, the market for similar
securities and other factors including general economic conditions and the
current financial condition, results of operations and business prospects of the
Company. Although the Exchange Notes will generally be permitted to be resold or
otherwise transferred by non-affiliates of the Company without compliance with
the registration and prospectus delivery requirements of the Securities Act, the
Company does not intend to apply for a listing or quotation of the Exchange
Notes on any securities exchange or stock market. One of the Initial Purchasers
has informed the Company that it currently intends to make a market in the
Exchange Notes. However, such Initial Purchaser is not obligated to do so, and
any such market-making may be discontinued at any time without notice. In
addition, such market-making activity will be subject to the limits imposed
under the Exchange Act. Accordingly, there can be no assurance as to the
development, liquidity or maintenance of any market for the Exchange Notes (or
in the case of non-tendering holders of Old Notes, the trading market for the
Old Notes following the Exchange Offer). If no trading market develops or is
maintained for the Exchange Notes, holders may experience difficulty in
reselling the Exchange Notes or may be unable to sell them.
The liquidity of, and trading market for, the Old Notes or the Exchange
Notes also may be adversely affected by general declines in the market for
similar securities. Such a decline may adversely affect such liquidity and
trading markets independent of the financial performance of, and prospects for,
the Company.
CONSEQUENCES OF EXCHANGE AND FAILURE TO EXCHANGE
Holders of Old Notes who do not exchange their Old Notes for Exchange Notes
pursuant to the Exchange Offer will continue to be subject to the restrictions
on transfer of such Old Notes as set forth in the legend thereon as a
consequence of the issuance of the Old Notes pursuant to exemptions from, or in
transactions not subject to, the registration requirements of the Securities Act
and applicable state securities laws. In general, the Old Notes may not be
offered or sold, unless registered under the Securities Act, except pursuant to
an exemption from, or in a transaction not subject to, the Securities Act and
applicable state securities laws. The Company does not currently anticipate that
it will register the Old Notes under the Securities Act. In addition, upon the
consummation of the Exchange Offer holders of Old Notes which remain outstanding
will not be entitled to any rights to have such Old Notes registered under the
Securities Act or to any similar rights under the Registration Rights Agreement,
subject to certain exceptions. To the extent that Old Notes are tendered and
accepted in the Exchange Offer, a holder's ability to sell untendered, or
tendered but unaccepted, Old Notes could be adversely affected.
INTEGRATION OF OPERATIONS; THE ACQUISITIONS
Tesoro does not have an operating history with respect to the Hawaii
Refinery (or any other operations of BHP Hawaii) or the Washington Refinery.
These Acquisitions are expected to triple Tesoro's annual revenues. There is no
assurance that, following the Acquisitions, the combination of entities will be
profitable, or will be able to achieve the potential cost savings, revenue
enhancements and operational improvements
22
<PAGE> 26
anticipated by Tesoro or that the projected demand for or prices of refinery
feedstocks and refined products assumed by Tesoro in connection with the
Acquisitions will be realized. Additionally, although Tesoro has conducted a due
diligence investigation in connection with each of the Acquisitions, the scope
of such investigations, particularly in light of the volume of environmental,
litigation and other matters to be investigated, has necessarily been limited.
Both the agreement to purchase BHP Hawaii (the "Hawaii Agreement") and the
Washington Agreement provide for indemnification with respect to breaches of
representations and warranties made therein and for additional indemnification,
subject to certain terms, conditions and limitations, with respect to other
matters. However, there can be no assurance that other material matters, not
identified or fully investigated in due diligence, will not subsequently be
identified or that the matters heretofore identified will not prove to be more
significant than currently expected, or that the indemnification provisions and
monetary limits thereon associated with each of the Acquisitions will be
sufficient to fully compensate the Company for any environmental or other losses
resulting in the future. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations -- Capital Resources and
Liquidity -- Environmental."
While BHP Hawaii and Shell Washington will operate as one or more wholly
owned subsidiaries of the Company, the success of the Acquisitions nevertheless
will depend in part on the ability of management of the Company to integrate the
operations of BHP Hawaii and Shell Washington with those of the Company and to
integrate various departments, systems and procedures. The integration of the
operations of BHP Hawaii and Shell Washington with those of the Company may
require substantial attention of management. The Company anticipates that it
will begin to realize cost savings and revenue enhancements in the fourth
quarter of 1998, with the full impact, which the Company estimates could
approximate $25 million annually, being achieved in the fiscal year ended
December 31, 1999; however, no assurance can be given that such cost savings and
revenue enhancements will be realized according to the anticipated time frame or
in such amount. Any inability of the Company to integrate the operations of BHP
Hawaii and Shell Washington with those of the Company in a timely and efficient
manner would adversely affect the Company's ability to realize its planned
revenue enhancements and cost savings.
HAWAII REFINED PRODUCT MARKET; ECONOMIC CONDITIONS IN HAWAII
In the Hawaiian refined product market, local refined product supply
currently is reasonably balanced to slightly surplus for all finished products
except jet fuel. This could limit the potential future growth in earnings
generated by the Hawaii Refinery. One competing gasoline marketer has begun
importing gasoline for retail sale in Hawaii. In addition, the growth rate in
Hawaii's gross state product from 1991 through 1997 was substantially below the
U.S. average. If these trends continue, they may have an adverse effect on the
business and results of operations of the Company.
HAWAIIAN STATE GOVERNMENT INVESTIGATIONS AND GASOLINE RETAILING RESTRICTIONS
In September 1990, the Attorney General for the State of Hawaii released a
preliminary report pursuant to an investigation under the Hawaii antitrust
statute indicating that the price of gasoline in Hawaii is persistently higher
than on the mainland. The Attorney General has not found any violations of
federal or state antitrust provisions in the investigation. However, the pricing
investigation remains open and all Hawaii gasoline retailers, including the
Company's Hawaii operations, may be subject to further inquiries and
documentation requests relating to their operations, costs and pricing policies.
In 1991 and 1993 at the request of independent gasoline dealers, the Hawaii
legislature enacted a series of two-year moratorium periods during which
refiners and jobbers were prevented or restricted from operating additional
retail stations pending the outcome of legislative studies. In 1995, legislation
was enacted which restricted refiners and jobbers to only one company-operated
station per dealer station opened, subject to a maximum of two company-operated
stations. In 1997, the Hawaii legislature ended the moratorium with the
enactment of a statute that permits refiners and jobbers to acquire or build any
number of retail stations, provided these are situated at least one-eighth of a
mile from any existing dealer station in the urban Honolulu area and at least
one-fourth of a mile from any existing dealer station in the remainder of the
State.
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VOLATILITY OF PRICES; EFFECT ON EARNINGS AND CASH FLOWS
The Company's refining and marketing earnings and cash flow from operations
are dependent upon the margin above fixed and variable expenses (including the
cost of crude oil feedstocks) at which the Company is able to sell refined
products. In recent years, the prices of crude oil and refined products have
fluctuated substantially. These prices depend on numerous factors, including the
demand for crude oil, gasoline and other refined products, which in turn depend
on, among other factors, changes in the economy, the level of foreign and
domestic production of crude oil and refined products, political conditions in
the Middle East, the availability of imports of crude oil and refined products,
the marketing of alternative and competing fuels and the extent of government
regulation. The prices received by the Company for its refined products are also
affected by local factors such as local market conditions and the level of
operations of other refineries in Alaska, Hawaii and Washington.
The price at which the Company can sell its refined products will be
strongly influenced by the commodity price of crude oil. Generally, an increase
or decrease in the price of crude oil results in a corresponding increase or
decrease in the price of gasoline and other refined products and could have a
significant short-term impact on the Company's refining operations and the
earnings and cash flow of the Company as a whole. However, each of the Company's
refineries maintains inventories of crude oil, intermediate products and refined
products, the value of each of which is subject to rapid fluctuations in market
prices. In addition, crude oil supply contracts are generally contracts with
market-responsive pricing provisions.
Any significant decline in the price for natural gas could have a material
adverse effect on the Company's exploration and production operations and the
financial condition of the Company as a whole. Prices for natural gas are
subject to wide fluctuations in response to relatively minor changes in the
supply of and demand for natural gas, market uncertainty and a variety of
additional factors that are beyond the control of the Company. These factors
include the domestic and foreign supply of natural gas, the level of consumer
demand, weather conditions, domestic and foreign government regulations, the
price and availability of alternative fuels and overall economic conditions.
While the Company from time to time enters into agreements with respect to a
portion of its future production in an effort to reduce price risk, including
commodity price contracts and forward sales agreements, there can be no
assurance that such transactions will reduce risk or mitigate the effect of any
substantial or prolonged decline in the price of natural gas.
CRUDE OIL SUPPLY
The Company believes an adequate supply of crude oil will be available to
its three refineries to sustain the Company's refining operations for the
foreseeable future at substantially the levels currently being experienced.
However, there can be no assurance that this situation will continue. If
additional supplemental crude oil becomes necessary at one or more of its
refineries, the Company intends to implement available alternatives that are
most advantageous under then prevailing conditions. Implementation of some
alternatives could require the consent or cooperation of third parties and other
considerations beyond the control of the Company. If the Company is unable to
obtain such supplemental crude oil volumes, or is only able to obtain such
volumes at uneconomic prices, the Company's results from operations could be
materially adversely effected. See "-- Government Regulations and Environmental
Risks."
RISKS ASSOCIATED WITH BOLIVIAN AND OTHER INTERNATIONAL OPERATIONS
The Company's international operations are primarily conducted in Bolivia,
where it has operated for over 20 years and where it currently explores for and
produces hydrocarbons through four contracts with the Bolivian government.
Substantially all of the Company's current Bolivian production is sold under
contract to the Bolivian government for export to Argentina, as there is
currently little internal demand in Bolivia for natural gas. As a result, the
Company's Bolivian operations are heavily dependent on its relations with the
Bolivian government. Moreover, a majority of the Company's Bolivian reserves are
currently shut-in. The Company believes that the completion of a 1,900-mile
pipeline currently under construction from Bolivia to Brazil will provide access
to gas-consuming markets. In addition, upon completion of the pipeline, the
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Company will face intense competition from major and independent natural gas
companies operating in Bolivia for a share of the contractual volumes to be
exported to Brazil. It is anticipated that each producer's share of the
contractual volumes will be allocated by YPFB (as defined herein) according to a
number of factors, including each producer's reserve volumes and production
capacity. Although the Company expects gas deliveries on the pipeline to begin
in early 1999, there can be no assurance that the pipeline will be operational
by such date. With the exception of the volumes currently under contract with
the Bolivian government, the Company cannot be assured of the amount of
additional volumes that will be exported to Brazil upon completion of the
pipeline. Upon completion of the Brazil gas pipeline, the Company's Bolivian gas
production will become dependent to a large extent upon the continued demand for
natural gas in Brazil and the stability of such markets. See "Management's
Discussion and Analysis of Financial Condition and Results of
Operations -- Exploration and Production -- Bolivia" and
"Business -- Exploration and Production -- Bolivia."
The future success of the Company's international operations in Bolivia and
elsewhere is subject to political, economic and other uncertainties, including,
among others, risk of war, revolution, border disputes, expropriation,
renegotiation or modification of existing contracts, import, export and
transportation regulations and tariffs, taxation policies, including royalty and
tax increases and retroactive tax claims, exchange controls, currency
fluctuations and other uncertainties arising out of foreign government
sovereignty over the Company's international operations. The Company's
international operations may also be adversely affected by laws and policies of
the United States affecting foreign trade, taxation and investment. Furthermore,
in the event of a dispute arising from its Bolivian or other international
operations, the Company may be subject to the exclusive jurisdiction of foreign
courts or may not be successful in subjecting foreign persons to the
jurisdiction of courts in the United States. The Company believes Bolivia
possesses relatively stable political and economic environments in which to
operate; however, there can be no assurance that political and economic and
other uncertainties will not develop in Bolivia or neighboring countries. Such
uncertainty or instability could result in new governments or the adoption of
new policies that might assume a substantially more hostile attitude toward
foreign investment. In an extreme case, such a change could result in voiding
pre-existing contracts and/or expropriation of foreign-owned assets.
REPLACEMENT OF RESERVES
The future success of the Company's exploration and production operations
depends upon the ability to find, develop or acquire additional oil and gas
reserves that are economically recoverable. The proved reserves of the Company
will generally decline as reserves are depleted, except to the extent that the
Company conducts successful exploration or development activities, acquires
properties containing proved reserves, or both. In order to increase reserves
and production, the Company must continue its development and exploration
drilling and recompletion programs or undertake other replacement activities.
The Company's current strategy includes continuing to exploit its existing
properties, discovering new reserves through exploration and increasing its
reserve base through acquisitions of producing properties. There can be no
assurance, however, that the Company's planned exploration, development and
acquisition activities will result in significant additional reserves or that
the Company will have continuing success drilling productive wells at low
finding and development costs. For a discussion of the Company's reserves, see
"Business -- Exploration and Production -- U.S. -- Reserves" and
"Business -- Exploration and Production -- Bolivia -- Reserves."
DRILLING RISKS
Drilling activities are subject to many risks, including the risk that no
commercially productive reservoirs will be encountered. There can be no
assurance that new wells drilled by the Company will be productive or that the
Company will recover all or any portion of its investment. Drilling for oil and
natural gas may involve unprofitable efforts, not only from dry wells, but from
wells that are productive but do not produce sufficient net revenues to return a
profit after drilling, completing, operating, and other costs. The cost of
drilling, completing and operating wells is often uncertain. The Company's
drilling operations may be curtailed, delayed or canceled as a result of
numerous factors, many of which are beyond the Company's control,
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including title problems, weather conditions, compliance with governmental
requirements and shortages or delays in the delivery of equipment and services.
RELIANCE ON ESTIMATES OF PROVED RESERVES
There are numerous uncertainties inherent in estimating quantities of
proved reserves, including many factors beyond the control of the Company. The
Company's historical reserve information set forth in this Prospectus represents
estimates based on evaluations audited by Netherland, Sewell & Associates, Inc.,
as of December 31, 1997.
Petroleum engineering is not an exact science. Information relating to the
Company's proved oil and gas reserves is based upon engineering estimates.
Estimates of economically recoverable oil and gas reserves and of future net
cash flows necessarily depend upon a number of variable factors and assumptions,
such as historical production from the area compared with production from other
producing areas, the assumed effects of regulations by governmental agencies and
assumptions concerning future oil and gas prices, future operating costs,
severance and excise taxes, development costs and workover and remedial costs,
all of which may in fact vary considerably from actual results. For these
reasons, estimates of the economically recoverable quantities of oil and gas
attributable to any particular group of properties, classifications of such
reserves based on risk of recovery and estimates of the future net cash flows
expected therefrom prepared by different engineers or by the same engineers at
different times may vary substantially. Actual production, revenues and
expenditures with respect to the Company's reserves will likely vary from
estimates, and such variances may be material. See "Business -- Exploration and
Production -- U.S. -- Reserves" and "Business -- Exploration and
Production -- Bolivia -- Reserves."
The Pre-Tax PV10 referred to in this Prospectus should not be construed as
the current market value of the estimated oil and gas reserves attributable to
the Company's properties. In accordance with applicable requirements of the
Commission, the estimated discounted future net cash flows from proved reserves
are generally based on prices and costs as of the date of the estimate, whereas
actual future prices and costs may be materially higher or lower. Actual future
net cash flows also will be affected by factors such as the amount and timing of
actual production, supply and demand for oil and gas, curtailments or increases
in consumption by gas purchasers and changes in governmental regulations or
taxation. The timing of actual future net cash flows from proved reserves, and
thus their actual present value, will be affected by the timing of both the
production and the incurrence of expenses in connection with development and
production of oil and gas properties. In addition, the 10% discount factor,
which is required by the Commission to be used to calculate discounted future
net cash flows for reporting purposes, is not necessarily the most appropriate
discount factor based on interest rates in effect from time to time and risks
associated with the Company or the oil and gas industry in general.
OPERATING HAZARDS AND UNINSURED RISKS
The Company's operations are subject to hazards and risks inherent in
drilling for, producing and transporting oil and natural gas and refining crude
oil, such as fires, natural disasters, explosions, blowouts, cratering, pipeline
ruptures, and spills, any of which can result in loss of hydrocarbons,
environmental pollution, personal injury claims, and other damage to properties
of the Company and others. As protection against operating hazards, the Company
maintains insurance coverage against some, but not all, potential losses. The
Company's coverages include, but are not limited to, operator's extra expense,
physical damage on certain assets, employer's liability, comprehensive general
liability, automobile, workers' compensation and loss of production income
insurance. The Company believes that its insurance is adequate and customary for
companies of a similar size engaged in operations similar to those of the
Company, but losses could occur for uninsurable or uninsured risks or in amounts
in excess of existing insurance coverage. The occurrence of an event that is not
fully covered by insurance could have an adverse impact on the Company's
financial condition and results of operations.
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CONCENTRATION OF OPERATIONS
A significant portion of the Company's domestic exploration and production
operations are located in the Wilcox Trend along the Texas and Louisiana Gulf
Coast. At December 31, 1997, approximately 39% of the Company's domestic net
proved gas reserves were located in the Bob West Field, which is located in the
Wilcox Trend. Similarly, all of the Company's international exploration and
production activities are located within two production blocks in Bolivia. As a
result, any interruption of the Company's production in the Bob West Field or in
Bolivia due to any one or more of a variety of conditions and events, including
natural disaster, reservoir damage, mechanical difficulties, unavailability of
equipment and supplies, transportation problems, title and contractual
controversies, government regulation or international political uncertainties
could have a material adverse effect on the Company's operations and its ability
to service the Notes. See "Business -- Exploration and
Production -- U.S. -- Reserves" and "Business -- Exploration and
Production -- Bolivia -- Reserves."
The Company's refining activities currently are conducted at its three
refineries in Hawaii, Alaska and Washington. The refineries are three of the
Company's principal operating assets. As a result, the operations of the
Company, and its ability to service the Notes, are subject to significant
interruption if one or more of the refineries were to experience a major
accident, be damaged by severe weather or other natural disaster, or otherwise
be forced to shut down. Although the Company maintains business interruption
insurance against some types of risks in amounts which the Company believes to
be economically prudent, if the refineries were to experience an interruption in
operations, the Company's business could be materially adversely affected. See
"Business -- Refining and Marketing."
COMPETITION
The petroleum industry is highly competitive in all phases, including the
refining of crude oil and the marketing of refined petroleum products, the
search for and development of oil and natural gas reserves and the marine
services business. The industry also competes with other industries that supply
the energy and fuel requirements of industrial, commercial and individual
consumers. The Company competes with a substantial number of major integrated
oil companies and other companies having materially greater financial and other
resources than the Company. These competitors have a greater ability to bear the
economic risks inherent in all phases of the industry. In addition, unlike the
Company, many of its competitors produce large volumes of crude oil which can
then be used in connection with their refining operations. See
"Business -- Competition and Other."
GOVERNMENT REGULATIONS AND ENVIRONMENTAL RISKS
The Company's operations are subject to a variety of foreign, federal,
state and local environmental laws and regulations governing the discharge of
pollutants into the air, soil, and water and the generation, treatment, storage,
transportation and disposal of solid and hazardous waste and materials.
Environmental laws and regulations that affect the Company's operations,
processes and margins have become and are becoming increasingly stringent.
Examples are the Clean Air Act Amendments of 1990 (the "Clean Air Act
Amendments") and other additional environmental regulations adopted by the
United States Environmental Protection Agency (the "EPA") and state and local
environmental agencies to implement the Clean Air Act Amendments. Although the
Company believes that it conducts its exploration and production, refining and
marketing and marine services operations in substantial compliance with existing
environmental laws and regulations, the Company cannot predict the nature, scope
or effect of legislation or regulatory requirements that could be imposed or how
existing or future laws or regulations will be administered or interpreted with
respect to products or activities to which they have not been previously
applied. Compliance with more stringent laws or regulations, as well as more
vigorous enforcement policies of the regulatory agencies, could adversely affect
the financial position and the results of operations of the Company and could
require substantial expenditures by the Company. See "Business -- Government
Regulation and Legislation."
Under the agreement related to the Washington Acquisition, Shell Refining
Holding Company, a subsidiary of Shell, generally has agreed to indemnify the
Company for environmental liabilities at the
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Washington Refinery arising out of conditions which existed at or prior to the
closing date. However, the Company is responsible for the first $0.5 million in
environmental costs in each year and 50% of environmental costs over $1 million
in each year, subject to a maximum aggregate liability of $5 million. While
Tesoro has done environmental investigations of the Washington and Hawaii
Refineries there is no assurance that the indemnified amounts will be adequate
with respect to future environmental claims or the remediation of existing or
unknown environmental conditions.
The Company's Refining and Marketing segment operates in environmentally
sensitive coastal waters, where tanker and pipeline operations are closely
regulated by local and Federal agencies and monitored by environmental interest
groups. Each of the Company's Refineries imports crude oil feedstocks by tanker.
Transportation of crude oil and refined product by tanker involves inherent risk
and, additionally, subjects the Company to the provisions of the Federal Oil
Pollution Act of 1990 ("OPA 90"), and state laws in Alaska, Hawaii and
Washington, which require the Company to demonstrate its capacity to respond to
a "worst case discharge" to the maximum extent possible. The Company has
contracted with various spill response service companies in the areas in which
the Company transports crude oil and refined product by tanker to meet the
requirements of OPA 90 and state laws. However, there can be no assurance that
there will not be any accidents involving tankers transporting crude oil or
refined product for the Company, or that such response services will respond to
a "worst case discharge" in a manner that will adequately contain such
discharge.
The Company's operations are inherently subject to accidental spills,
discharges or other releases of petroleum or hazardous substances which may give
rise to liability to governmental entities or private parties under foreign,
federal, state or local environmental laws, as well as under common law.
Although the Company has invested substantial resources to prevent future
accidental discharges and to remediate contamination resulting from prior
discharges, there can be no assurance that accidental discharges will not occur
in the future, that future action will not be taken in connection with past
discharges, that governmental agencies will not assess penalties against the
Company in connection with any past or future contamination, or that third
parties will not assert claims against the Company for damages allegedly arising
out of any past or future contamination.
The Company has been identified by the EPA as a potentially responsible
party ("PRP") pursuant to the Comprehensive Environmental Response, Compensation
and Liability Act ("CERCLA") for the D.L. Mud Superfund site in Abbeville,
Louisiana, but does not believe its liability at such site to be material. See
"Business -- Government Regulation and Legislation." In addition, while the
Company from time to time has been, and presently is, subject to litigation and
investigations with respect to environmental and related matters, the Company
does not believe that such proceedings will have a material adverse effect on
the results of operations or competitive position of the Company. See
"Business -- Legal Proceedings." However, there can be no assurance that the
Company will not become involved in further litigation or other proceedings, or
that if the Company were to be held responsible for damages in any litigation or
proceedings (including existing ones), such costs would not be material.
The Company has in the past operated service stations with underground
storage tanks ("USTs") in various jurisdictions, and currently operates service
stations in Alaska and Hawaii which have USTs. All such storage tanks are
subject to governmental regulation and legislation. See "Business -- Government
Regulation and Legislation." The operation of USTs also poses certain risks
apart from costs associated with regulatory requirements. These risks are
predominantly damages associated with the underground leaks to soil and
groundwater of petroleum products. The Company currently has leak detection and
tank testing programs in effect to mitigate the threat of such risks. However,
there can be no assurance that leaks from USTs at one or more of the Company's
service stations will not occur, or that previously operated service stations do
not have impacted soil or groundwater that could result in fines or civil
liability for the Company.
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THE EXCHANGE OFFER
PURPOSE AND EFFECT OF THE EXCHANGE OFFER
The Old Notes were sold by the Company on July 2, 1998, to the Initial
Purchasers pursuant to the Purchase Agreement. The Initial Purchasers
subsequently resold all of the Old Notes to Qualified Institutional Buyers (as
defined in Rule 144A), each of whom agreed to comply with certain transfer
restrictions and other conditions. As a condition to the purchase of the Old
Notes by the Initial Purchasers, the Company entered into the Registration
Rights Agreement with the Initial Purchasers, which requires, among other
things, that promptly following the issuance and sale of the Old Notes, the
Company file with the SEC the Registration Statement with respect to the
Exchange Notes, use its best efforts to cause the Registration Statement to
become effective under the Securities Act and, upon the effectiveness of the
Registration Statement, offer to the holders of the Old Notes the opportunity to
exchange their Old Notes for a like principal amount of Exchange Notes, which
will be issued without a restrictive legend and may be reoffered and resold by
the holder without restrictions or limitations under the Securities Act subject
to certain exceptions described below. A copy of the Registration Rights
Agreement has been filed as an exhibit to the Registration Statement of which
this Prospectus is a part. The term "holder" with respect to the Exchange Offer
means any person in whose name Old Notes are registered on the Company's books
or any other person who has obtained a properly completed bond power from the
registered holder or any person whose Old Notes are held of record by the
Depositary who desires to deliver such Old Notes by book-entry transfer of the
Depositary.
Based on existing interpretations of the Securities Act by the staff of the
SEC set forth in several no-action letters to third parties, and subject to the
immediately following sentence, the Company believes that Exchange Notes issued
pursuant to the Exchange Offer in exchange for Old Notes may be offered for
resale, resold and otherwise transferred by a holder thereof (other than (i) a
broker-dealer who purchased such Old Notes directly from the Company for resale
pursuant to Rule 144A or any other available exemption under the Securities Act
or (ii) a person that is an "affiliate" (within the meaning of Rule 405 of the
Securities Act) of the Company), without compliance with the registration and
prospectus delivery provisions of the Securities Act, provided that the holder
is acquiring the Exchange Notes in its ordinary course of business and is not
participating, and has no arrangement or understanding with any person to
participate, in the distribution of the Exchange Notes. However, any purchaser
of Old Notes who is an affiliate of the Company or who intends to participate in
the Exchange Offer for the purpose of distributing the Exchange Notes, or any
broker-dealer who purchased the Old Notes from the Company to resell pursuant to
Rule 144A or any other available exemption under the Securities Act, (i) will
not be able to rely on the interpretations by the staff of the SEC set forth in
such no-action letters, (ii) will not be able to tender its Old Notes in the
Exchange Offer and (iii) must comply with the registration and prospectus
delivery requirements of the Securities Act in connection with any sale or
transfer of the Old Notes unless such sale or transfer is made pursuant to an
exemption from such requirements. Accordingly, any holder who tenders in the
Exchange Offer with the intention to participate, or for the purpose of
participating, in a distribution of the Exchange Notes must comply with the
registration and prospectus delivery requirements of the Securities Act in
connection with a secondary resale transaction. See "Plan of Distribution."
As a result of the filing and effectiveness of the Registration Statement
of which this Prospectus is a part, the Company will not be required to pay an
increased interest rate on the Old Notes. Following the consummation of the
Exchange Offer, holders of Old Notes not tendered will not have any further
registration rights except in certain limited circumstances requiring the filing
of a Shelf Registration Statement (as defined), and the Old Notes will continue
to be subject to certain restrictions on transfer. See "Description of the
Notes -- Registration Rights; Liquidated Damages." Accordingly, the liquidity of
the market for the Old Notes could be adversely affected.
TERMS OF THE EXCHANGE OFFER
Upon the terms and subject to the conditions set forth in this Prospectus
and in the Letter of Transmittal, the Company will accept all Old Notes properly
tendered and not withdrawn prior to 5:00 p.m. New York City
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time, on the Expiration Date. After authentication of the Exchange Notes by the
Trustee or an authenticating agent, the Company will issue and deliver $1,000
principal amount of Exchange Notes in exchange for each $1,000 principal amount
of outstanding Old Notes accepted in the Exchange Offer. Holders may tender some
or all of their Old Notes pursuant to the Exchange Offer in denominations of
$1,000 and integral multiples thereof.
Each holder of Old Notes who wishes to exchange Old Notes for Exchange
Notes in the Exchange Offer will be required to represent that (i) it is not an
affiliate of the Company, (ii) any Exchange Notes to be received by it were
acquired in the ordinary course of its business and (iii) it has no arrangement
or understanding with any person to participate in the distribution (within the
meaning of the Securities Act) of the Exchange Notes.
Each broker-dealer that receives Exchange Notes for its own account in
exchange for Old Notes, where such Old Notes were acquired by such broker-dealer
as a result of market-making activities or other trading activities, must
acknowledge that it will deliver a prospectus in connection with any resale of
such Exchange Notes. See "Plan of Distribution."
The form and terms of the Exchange Notes are identical in all material
respects to the form and terms of the Old Notes, except that (i) the offering of
the Exchange Notes has been registered under the Securities Act, (ii) the
Exchange Notes will not be subject to transfer restrictions and (iii) the
holders of the Exchange Notes will not be entitled to registration or other
rights under the Registration Rights Agreement including the provision for
payment of Liquidated Damages upon failure by the Company to consummate the
Exchange Offer or the occurrence of certain other events. The Exchange Notes
will evidence the same debt as the Old Notes. The Exchange Notes will be issued
under and entitled to the benefits of the Indenture.
As of the date of this Prospectus, $300,000,000 aggregate principal amount
of the Old Notes is outstanding. In connection with the issuance of the Old
Notes, the Company arranged for the Old Notes to be issued and transferable in
book-entry form through the facilities of the Depositary, acting as depositary.
The Exchange Notes will also be issuable and transferable in book-entry form
through the Depositary.
This Prospectus, together with the accompanying Letter of Transmittal, is
initially being sent to all registered holders of the Old Notes as of the close
of business on August 7, 1998. The Company intends to conduct the Exchange Offer
in accordance with the applicable requirements of the Exchange Act, and the
rules and regulations of the SEC thereunder, including Rule 14e-1, to the extent
applicable. The Exchange Offer is not conditioned upon any minimum aggregate
principal amount of Old Notes being tendered, and holders of the Old Notes do
not have any appraisal or dissenters' rights under the Delaware General
Corporation Law or under the Indenture in connection with the Exchange Offer.
The Company shall be deemed to have accepted validly tendered Old Notes when, as
and if the Company has given oral or written notice thereof to the Exchange
Agent. See "-- Exchange Agent." The Exchange Agent will act as agent for the
tendering holders for the purpose of receiving Exchange Notes from the Company
and delivering Exchange Notes to such holders.
If any tendered Old Notes are not accepted for exchange because of an
invalid tender or the occurrence of certain other events set forth herein,
certificates for any such unaccepted Old Notes will be returned, at the
Company's cost, to the tendering holder thereof as promptly as practicable after
the Expiration Date.
Holders who tender Old Notes in the Exchange Offer will not be required to
pay brokerage commissions or fees or, subject to the instructions in the Letter
of Transmittal, transfer taxes with respect to the exchange of Old Notes
pursuant to the Exchange Offer. The Company will pay all charges and expenses,
other than certain applicable taxes, in connection with the Exchange Offer. See
"-- Solicitation of Tenders; Fees and Expenses."
NEITHER THE BOARD OF DIRECTORS OF THE COMPANY NOR THE COMPANY MAKES ANY
RECOMMENDATION TO HOLDERS OF OLD NOTES AS TO WHETHER TO TENDER OR REFRAIN FROM
TENDERING ALL OR ANY PORTION OF THEIR OLD NOTES PURSUANT TO THE EXCHANGE OFFER.
MOREOVER, NO ONE HAS BEEN AUTHORIZED TO MAKE ANY SUCH RECOMMENDATION. HOLDERS OF
OLD NOTES MUST MAKE THEIR OWN DECISION
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WHETHER TO TENDER PURSUANT TO THE EXCHANGE OFFER AND, IF SO, THE
AGGREGATE AMOUNT OF OLD NOTES TO TENDER AFTER READING THIS PROSPECTUS AND THE
LETTER OF TRANSMITTAL AND CONSULTING WITH THEIR ADVISORS, IF ANY, BASED ON THEIR
OWN FINANCIAL POSITION AND REQUIREMENTS.
EXPIRATION DATE; EXTENSIONS; AMENDMENTS
The term "Expiration Date" shall mean 5:00 p.m., New York City time, on
September 11, 1998, unless the Company, in its sole discretion, extends the
Exchange Offer, in which case the term "Expiration Date" shall mean the latest
date to which the Exchange Offer is extended. The Company may extend the
Exchange Offer at any time and from time to time by giving oral or written
notice to the Exchange Agent and by timely public announcement via the Dow Jones
News Service.
The Company expressly reserves the right in its sole discretion (i) to
delay acceptance of any Old Notes, to extend the Exchange Offer or to terminate
the Exchange Offer and to refuse to accept Old Notes not previously accepted, if
any of the conditions set forth herein under "-- Conditions to the Exchange
Offer" shall have occurred and shall not have been waived by the Company (if
permitted to be waived by the Company), by giving oral or written notice of such
delay, extension or termination to the Exchange Agent and (ii) to amend the
terms of the Exchange Offer in any manner. Any such delay in acceptance,
extension, termination or amendment will be followed as promptly as practicable
by oral or written notice thereof by the Company to the registered holders of
the Old Notes. If the Exchange Offer is amended in a manner determined by the
Company to constitute a material change, the Company will promptly disclose such
amendment in a manner reasonably calculated to inform the holders of such
amendment and the Company will extend the Exchange Offer to the extent required
by law.
Without limiting the manner in which the Company may choose to make public
announcements of any delay in acceptance, extension, termination or amendment of
the Exchange Offer, the Company shall have no obligation to publish, advise or
otherwise communicate any such public announcement, other than by making a
timely release thereof to the Dow Jones News Service.
INTEREST ON THE EXCHANGE NOTES
The Exchange Notes will bear interest at a rate of 9% per annum, payable
semiannually on January 1 and July 1 of each year, commencing January 1, 1999.
Holders of Exchange Notes of record on December 15, will receive on January 1,
1999, an interest payment in an amount equal to (i) the accrued interest on such
Exchange Notes from the date of issuance thereof to January 1, 1999, plus (ii)
the accrued interest on the previously held Old Notes from the date of issuance
of such Old Notes (July 2, 1998) to the date of exchange thereof. The Notes
mature on July 1, 2008.
PROCEDURES FOR TENDERING OLD NOTES
Each holder of Old Notes wishing to accept the Exchange Offer must
complete, sign and date the Letter of Transmittal, or a facsimile thereof, in
accordance with the instructions contained herein and therein, and mail or
otherwise deliver such Letter of Transmittal, or such facsimile, together with
the Old Notes to be exchanged and any other required documentation, to U.S. Bank
Trust National Association, as Exchange Agent, at the address set forth herein
and in the Letter of Transmittal or effect a tender of Old Notes pursuant to the
procedures for book-entry transfer as provided for herein and therein. By
executing the Letter of Transmittal, each holder will represent to the Company,
that, among other things, the Exchange Notes acquired pursuant to the Exchange
Offer are being acquired in the ordinary course of business of the person
receiving such Exchange Notes, whether or not such person is the holder, that
neither the holder nor any such other person has any arrangement or
understanding with any person to participate in the distribution of such
Exchange Notes and that neither the holder nor any such other person is an
"affiliate,"as defined in Rule 405 under the Securities Act, of the Company.
Any financial institution that is a participant in the Depositary's
Book-Entry Transfer Facility system may make book-entry delivery of the Old
Notes by causing the Depositary to transfer such Old Notes into the
31
<PAGE> 35
Exchange Agent's account in accordance with the Depositary's procedure for such
transfer. Although delivery of Old Notes may be effected through book-entry
transfer into the Exchange Agent's account at the Depositary, the Letter of
Transmittal (or facsimile thereof), with any required signature guarantees and
any other required documents, must, in any case, be transmitted to and received
by the Exchange Agent at its address set forth herein under "-- Exchange Agent"
prior to 5:00 p.m., New York City time, on the Expiration Date. DELIVERY OF
DOCUMENTS TO THE DEPOSITARY IN ACCORDANCE WITH ITS PROCEDURES DOES NOT
CONSTITUTE DELIVERY TO THE EXCHANGE AGENT. See "-- Book-Entry Transfer."
Only a holder may tender its Old Notes in the Exchange Offer. To tender in
the Exchange Offer, a holder must complete, sign and date the Letter of
Transmittal or a facsimile thereof, have the signatures thereof guaranteed if
required by the Letter of Transmittal, and mail or otherwise deliver such Letter
of Transmittal or such facsimile, together with the Old Notes (unless such
tender is being effected pursuant to the procedure for book-entry transfer) and
any other required documents, to the Exchange Agent for receipt, prior to 5:00
p.m., New York City time, on the Expiration Date.
The Tender by a holder will constitute an agreement among such holder, the
Company and the Exchange Agent in accordance with the terms and subject to the
conditions set forth herein and in the Letter of Transmittal. If less than all
of the Old Notes are tendered, a tendering holder should fill in the amount of
Old Notes being tendered in the appropriate box on the Letter of Transmittal.
The entire amount of Old Notes delivered to the Exchange Agent will be deemed to
have been tendered unless otherwise indicated.
THE LETTER OF TRANSMITTAL WILL INCLUDE REPRESENTATIONS TO THE COMPANY THAT,
AMONG OTHER THINGS, (1) THE EXCHANGE NOTES ACQUIRED PURSUANT TO THE EXCHANGE
OFFER ARE BEING ACQUIRED IN THE ORDINARY COURSE OF BUSINESS OF THE PERSON
RECEIVING SUCH EXCHANGE NOTES (WHETHER OR NOT SUCH PERSON IS THE HOLDER), (2)
NEITHER THE HOLDER NOR ANY SUCH OTHER PERSON IS ENGAGED IN, INTENDS TO ENGAGE IN
OR HAS ANY ARRANGEMENT OR UNDERSTANDING WITH ANY PERSON TO PARTICIPATE IN THE
DISTRIBUTION OF SUCH EXCHANGE NOTES, (3) NEITHER THE HOLDER NOR ANY SUCH OTHER
PERSON IS AN "AFFILIATE" (AS DEFINED IN RULE 405 UNDER THE SECURITIES ACT), OF
THE COMPANY AND (4) IF THE TENDERING HOLDER IS A BROKER OR DEALER (AS DEFINED IN
THE EXCHANGE ACT) (A) IT ACQUIRED THE OLD NOTES FOR ITS OWN ACCOUNT AS A RESULT
OF MARKET-MAKING ACTIVITIES OR OTHER TRADING ACTIVITIES AND (B) IT HAS NOT
ENTERED INTO ANY ARRANGEMENT OR UNDERSTANDING WITH THE COMPANY OR ANY
"AFFILIATE" THEREOF TO DISTRIBUTE THE EXCHANGE NOTES TO BE RECEIVED IN THE
EXCHANGE OFFER. IN THE CASE OF A BROKER-DEALER THAT RECEIVES EXCHANGE NOTES FOR
ITS OWN ACCOUNT IN EXCHANGE FOR OLD NOTES WHICH WERE ACQUIRED BY IT AS A RESULT
OF MARKET-MAKING OR OTHER TRADING ACTIVITIES, THE LETTER OF TRANSMITTAL WILL
ALSO INCLUDE AN ACKNOWLEDGMENT THAT THE BROKER-DEALER WILL DELIVER A COPY OF
THIS PROSPECTUS IN CONNECTION WITH THE RESALE BY IT OF EXCHANGE NOTES RECEIVED
PURSUANT TO THE EXCHANGE OFFER; HOWEVER, BY SO ACKNOWLEDGING AND BY DELIVERING A
PROSPECTUS, SUCH HOLDER WILL NOT BE DEEMED TO ADMIT THAT IT IS AN "UNDERWRITER"
WITHIN THE MEANING OF THE SECURITIES ACT. SEE "PLAN OF DISTRIBUTION."
THE METHOD OF DELIVERY OF OLD NOTES, THE LETTER OF TRANSMITTAL AND ALL
OTHER REQUIRED DOCUMENTS TO THE EXCHANGE AGENT IS AT THE ELECTION AND RISK OF
THE HOLDERS. INSTEAD OF DELIVERY BY MAIL, IT IS RECOMMENDED THAT HOLDERS USE AN
OVERNIGHT OR HAND DELIVERY SERVICE. IN ALL CASES, SUFFICIENT TIME SHOULD BE
ALLOWED TO ENSURE DELIVERY TO THE EXCHANGE AGENT PRIOR TO THE EXPIRATION DATE.
NO LETTER OF TRANSMITTAL OR OLD NOTES SHOULD BE SENT TO THE COMPANY. HOLDERS MAY
ALSO REQUEST THAT THEIR RESPECTIVE BROKERS, DEALERS, COMMERCIAL BANKS, TRUST
COMPANIES OR NOMINEES EFFECT SUCH TENDER FOR HOLDERS, IN EACH CASE AS SET FORTH
HEREIN AND IN THE LETTER OF TRANSMITTAL.
Any beneficial owner whose Old Notes are registered in the name of his
broker, dealer, commercial bank, trust company or other nominee and who wishes
to tender should contact such registered holder promptly and instruct such
registered holder to tender on his behalf. If such beneficial owner wishes to
tender on his own behalf, such beneficial owner must, prior to completing and
executing the Letter of Transmittal and delivering his Old Notes, either make
appropriate arrangements to register ownership of the Old Notes in such owner's
32
<PAGE> 36
name or obtain a properly completed bond power from the registered holder. The
transfer of record ownership may take considerable time.
Signatures on a Letter of Transmittal or a notice of withdrawal, as the
case may be, must be guaranteed by a member firm of a registered national
securities exchange or of the National Association of Securities Dealers, Inc.,
a commercial bank or trust company having an office or correspondent in the
United States or an "eligible guarantor institution" within the meaning of Rule
17Ad-15 under the Exchange Act (each an "Eligible Institution"), unless the Old
Notes tendered pursuant thereto are tendered (i) by a registered holder who has
not completed the box entitled "Special Registration Instructions" or "Special
Delivery Instructions" of the Letter of Transmittal or (ii) for the account of
an Eligible Institution. If the Letter of Transmittal is signed by a person
other than the registered holder listed therein, such Old Notes must be endorsed
or accompanied by appropriate bond powers which authorize such person to tender
the Old Notes on behalf of the registered holder, in either case signed as the
name of the registered holder or holders appears on the Old Notes. If the Letter
of Transmittal or any Old Notes or bond powers are signed or endorsed by
trustees, executors, administrators, guardians, attorneys-in-fact, officers of
corporations or others acting in a fiduciary or representative capacity, such
person should so indicate when signing, and unless waived by the Company,
evidence satisfactory to the Company of their authority to so act must be
submitted with the Letter of Transmittal.
All questions as to the validity, form, eligibility (including time of
receipt), acceptance and withdrawal of the tendered Old Notes will be determined
by the Company in its sole discretion, which determination will be final and
binding. The Company reserves the absolute right to reject any and all Old Notes
not properly tendered or any Old Notes the Company's acceptance of which would,
in the opinion of counsel for the Company, be unlawful. The Company also
reserves the absolute right to waive irregularities or conditions of tender as
to particular Old Notes. The Company's interpretation of the terms and
conditions of the Exchange Offer (including the instructions in the Letter of
Transmittal) will be final and binding on all parties. Unless waived, any
defects or irregularities in connection with tenders of Old Notes must be cured
within such time as the Company shall determine. Although the Company intends to
notify holders of defects or irregularities with respect to tenders of Old
Notes, neither the Company, the Exchange Agent nor any other person shall be
under any duty to give notification of defects or irregularities with respect to
tenders of Old Notes, nor shall any of them incur any liability for failure to
give such notification. Tenders of Old Notes will not be deemed to have been
made until such irregularities have been cured or waived. Any Old Notes received
by the Exchange Agent that the Company determines are not properly tendered or
the tender of which is otherwise rejected by the Company, and as to which the
defects or irregularities have not been cured or waived by the Company, will be
returned by the Exchange Agent to the tendering holder, unless otherwise
provided in the Letter of Transmittal, as soon as practicable following the
Expiration Date.
In addition, the Company reserves the right in its sole discretion (i) to
purchase or make offers for any Old Notes that remain outstanding subsequent to
the Expiration Date or, as set forth under "-- Conditions to the Exchange
Offer," terminate the Exchange Offer and (ii) to the extent permitted by
applicable law, to purchase Old Notes in the open market, in privately
negotiated transactions or otherwise. The terms of any such purchases or offers
may differ from the terms of the Exchange Offer.
BOOK-ENTRY TRANSFER
The Company understands that the Exchange Agent will make a request
promptly after the date of this Prospectus to establish accounts with respect to
the Old Notes at the DTC (the "Book-Entry Transfer Facility") for the purpose of
facilitating the Exchange Offer, and subject to the establishment thereof, any
financial institution that is a participant in the Book-Entry Transfer
Facility's system may make book-entry delivery of Old Notes by causing such
Book-Entry Transfer Facility to transfer such Old Notes into the Exchange
Agent's account with respect to the Old Notes in accordance with the Book-Entry
Transfer Facility's procedures for such transfer. ALTHOUGH DELIVERY OF OLD NOTES
MAY BE EFFECTED THROUGH BOOK-ENTRY TRANSFER INTO THE EXCHANGE AGENT'S ACCOUNT AT
THE BOOK-ENTRY TRANSFER FACILITY, AN APPROPRIATE LETTER OF TRANSMITTAL PROPERLY
COMPLETED AND DULY EXECUTED WITH ANY REQUIRED SIGNATURE GUARANTEE AND ALL OTHER
REQUIRED DOCUMENTS MUST IN EACH CASE BE TRANSMITTED TO AND RECEIVED OR CONFIRMED
BY THE EXCHANGE AGENT AT
33
<PAGE> 37
ITS ADDRESS SET FORTH BELOW ON OR PRIOR TO THE EXPIRATION DATE OR, IF THE
GUARANTEED DELIVERY PROCEDURES DESCRIBED BELOW ARE COMPLIED WITH, WITHIN THE
TIME PERIOD PROVIDED UNDER SUCH PROCEDURES. DELIVERY OF DOCUMENTS TO THE
BOOK-ENTRY TRANSFER FACILITY DOES NOT CONSTITUTE DELIVERY TO THE EXCHANGE AGENT.
GUARANTEED DELIVERY PROCEDURES
Holders who wish to tender their Old Notes and (i) whose Old Notes are not
immediately available, or (ii) who cannot deliver their Old Notes, the Letter of
Transmittal or any other required documents to the Exchange Agent prior to the
Expiration Date, or who cannot complete the procedure for book-entry transfer on
a timely basis, may effect a tender if:
(a) the tender is made through an Eligible Institution;
(b) prior to the Expiration Date, the Exchange Agent receives from
such Eligible Institution a properly completed and duly executed Notice of
Guaranteed Delivery (by facsimile transmittal, mail or hand delivery)
setting forth the name and address of the holder, the certificate number or
numbers of such holder's Old Notes and the principal amount of such Old
Notes tendered, stating that the tender is being made thereby, and
guaranteeing that, within three New York Stock Exchange ("NYSE") trading
days after the Expiration Date, the Letter of Transmittal (or facsimile
thereof), together with the certificate(s) representing the Old Notes to be
tendered in proper form for transfer (or confirmation of a book-entry
transfer into the Exchange Agent's account at the Depositary of Old Notes
delivered electronically) and any other documents required by the Letter of
Transmittal, will be deposited by the Eligible Institution with the
Exchange Agent; and
(c) such properly completed and executed Letter of Transmittal (or
facsimile thereof), together with the certificate(s) representing all
tendered Old Notes in proper form for transfer (or confirmation of a
book-entry transfer into the Exchange Agent's account at the Depositary of
Old Notes delivered electronically) and all other documents required by the
Letter of Transmittal are received by the Exchange Agent within three NYSE
trading days after the Expiration Date.
Upon request to the Exchange Agent, a Notice of Guaranteed Delivery will be
sent to holders who wish to tender their Old Notes according to the guaranteed
delivery procedures set forth above.
WITHDRAWAL OF TENDERS
Except as otherwise provided herein, tenders of Old Notes may be withdrawn
at any time prior to 5:00 p.m., New York City time, on the Expiration Date.
For a withdrawal to be effective, a written or facsimile transmission
notice of withdrawal must be received by the Exchange Agent at its address set
forth herein prior to 5:00 p.m., New York City time, on the Expiration Date. Any
such notice of withdrawal must (i) specify the name of the person having
deposited the Old Notes to be withdrawn (the "Depositor"), (ii) identify the Old
Notes to be withdrawn (including the certificate number or numbers and principal
amount of such Old Notes or, in the case of Old Notes transferred by book-entry
transfer, the name and number of the account at the Depositary to be credited),
(iii) be signed by the Depositor in the same manner as the original signature on
the Letter of Transmittal by which such Old Notes were tendered (including any
required signature guarantee) or be accompanied by documents of transfer
sufficient to permit the Trustee with respect to the Old Notes to register the
transfer of such Old Notes into the name of the Depositor withdrawing the tender
and (iv) specify the name in which any such Old Notes are to be registered, if
different from that of the Depositor. All questions as to the validity, form and
eligibility (including time of receipt) of such withdrawal notices will be
determined by the Company, whose determination shall be final and binding on all
parties. Any Old Notes so withdrawn will be deemed not to have been validly
tendered for purposes of the Exchange Offer, and no Exchange Notes will be
issued with respect thereto unless the Old Notes so withdrawn are validly
retendered. Any Old Notes that have been tendered but are not accepted for
exchange will be returned to the holder thereof without cost to such holder as
soon as practicable after withdrawal, rejection of tender or termination of the
Exchange Offer.
34
<PAGE> 38
Properly withdrawn Old Notes may be retendered by following one of the
procedures described above under "-- Procedures for Tendering" at any time prior
to the Expiration Date.
CONDITIONS TO THE EXCHANGE OFFER
Notwithstanding any other term of the Exchange Offer, the Company will not
be required to accept for exchange, or to exchange Exchange Notes for, any Old
Notes, and may terminate or amend the Exchange Offer as provided herein before
the acceptance of such Old Notes if, in the Company's judgment, any of the
following conditions has occurred or exists or has not been satisfied: (i) that
the Exchange Offer, or the making of any exchange by a holder, violates
applicable law or any applicable interpretation of the staff of the SEC, (ii)
that any action or proceeding shall have been instituted or threatened in any
court or by or before any governmental agency or body with respect to the
Exchange Offer, (iii) that there has been adopted or enacted any law, statute,
rule or regulation that can reasonably be expected to impair the ability of the
Company to proceed with the Exchange Offer, (iv) that there has been declared by
United States federal or Texas or New York state authorities a banking
moratorium or (v) that trading on the American Stock Exchange or the NYSE or
generally in the United States over-the-counter market has been suspended by
order of the SEC or any other governmental agency in each of clauses (i) through
(iv) which, in the Company's judgment, would reasonably be expected to impair
the ability of the Company to proceed with the Exchange Offer.
If the Company determines that it may terminate the Exchange Offer for any
of the reasons set forth above, the Company may (i) refuse to accept any Old
Notes and return any Old Notes that have been tendered to the holders thereof,
(ii) extend the Exchange Offer and retain all Old Notes tendered prior to the
Expiration Date of the Exchange Offer, subject to the rights of such holders of
tendered Old Notes to withdraw their tendered Old Notes or (iii) waive such
termination event with respect to the Exchange Offer and accept all properly
tendered Old Notes that have not been withdrawn. If such waiver constitutes a
material change in the Exchange Offer, the Company will disclose such change by
means of a supplement to this Prospectus that will be distributed to each
registered holder, and the Company will extend the Exchange Offer for a period
of five to ten business days, depending upon the significance of the waiver and
the manner of disclosure to the registered holders, if the Exchange Offer would
otherwise expire during such period.
EXCHANGE AGENT
U.S. Bank Trust National Association, the Trustee under the Indenture, has
been appointed as Exchange Agent for the Exchange Offer. In such capacity, the
Exchange Agent has no fiduciary duties and will be acting solely on the basis of
directions of the Company. Requests for assistance and requests for additional
copies of this Prospectus or of the Letter of Transmittal should be directed to
the Exchange Agent addressed as follows:
U.S. Bank Trust National Association, Exchange Agent
<TABLE>
<S> <C> <C>
By Registered, Certified, By Hand: By First Class Mail:
or
Overnight Mail or
Courier: U.S. Bank Trust N.A. U.S. Bank Trust N.A.
4th Floor Bond Drop Window P.O. Box 64485
U.S. Bank Trust N.A. 180 East Fifth Street St. Paul, MN 55164-9549
Attn: Specialized Finance St. Paul, MN 55101
SPFT0414
180 East Fifth Street By Facsimile:
St. Paul, MN 55101 (For Eligible Institutions Only):
(651) 244-1537
To Confirm by Telephone
or for Information, Call:
(651) 244-1197
</TABLE>
35
<PAGE> 39
DELIVERY OF THE LETTER OF TRANSMITTAL TO AN ADDRESS OTHER THAN AS SET FORTH
ABOVE OR TRANSMISSION OF INSTRUCTIONS VIA FACSIMILE OTHER THAN AS SET FORTH
ABOVE WILL NOT CONSTITUTE A VALID DELIVERY OF SUCH LETTER OF TRANSMITTAL.
SOLICITATION OF TENDERS; FEES AND EXPENSES
The expenses of soliciting tenders pursuant to the Exchange Offer will be
borne by the Company. The principal solicitation pursuant to the Exchange Offer
is being made by mail. Additional solicitations may be made by officers and
regular employees of the Company and its affiliates in person, by telegraph,
telephone or telecopier.
The Company has not retained any dealer-manager in connection with the
Exchange Offer and will not make any payments to brokers, dealers or other
persons soliciting acceptances of the Exchange Offer. The Company will, however,
pay the Exchange Agent reasonable and customary fees for its services, reimburse
the Exchange Agent for its reasonable out-of-pocket costs and expenses in
connection therewith and indemnify the Exchange Agent for all losses and claims
incurred by it as a result of the Exchange Offer. The Company may also pay
brokerage houses and other custodians, nominees and fiduciaries the reasonable
out-of-pocket expenses incurred by them in forwarding copies of this Prospectus,
the Letter of Transmittal and related documents to the beneficial owners of the
Old Notes and in handling or forwarding tenders for exchange.
The expenses to be incurred in connection with the Exchange Offer,
including fees and expenses of the Exchange Agent and Trustee and accounting and
legal fees and printing costs, will be paid by the Company.
The Company will pay all transfer taxes, if any, applicable to the exchange
of Old Notes pursuant to the Exchange Offer. If, however, certificates
representing Exchange Notes or Old Notes for principal amounts not tendered or
accepted for exchange are to be delivered to, or are to be registered or issued
in the name of, any person other than the registered holder of the Old Notes
tendered, or if tendered Old Notes are registered in the name of any person
other than the person signing the Letter of Transmittal, or if a transfer tax is
imposed for any reason other than the exchange of Old Notes pursuant to the
Exchange Offer, then the amount of any such transfer taxes (whether imposed on
the registered holder or any other persons) will be payable by the tendering
holder. If satisfactory evidence of payment of such taxes or exemption therefrom
is not submitted with the Letter of Transmittal, the amount of such transfer
taxes will be billed by the Company directly to such tendering holder.
ACCOUNTING TREATMENT
The Exchange Notes will be recorded at the same carrying value as the Old
Notes, as reflected in the Company's accounting records on the date of the
exchange. Accordingly, no gain or loss for accounting purposes will be
recognized by the Company as a result of the consummation of the Exchange Offer.
The expenses of the Exchange Offer will be amortized by the Company over the
term of the Exchange Notes.
CONSEQUENCES OF FAILURE TO EXCHANGE
Participation in the Exchange Offer is voluntary. Holders of the Old Notes
are urged to consult their financial and tax advisors in making their own
decisions as to what action to take.
As a result of the making of, and upon acceptance for exchange of all
validly tendered Old Notes pursuant to the terms of, this Exchange Offer, the
Company will have fulfilled a covenant contained in the Registration Rights
Agreement. Holders of the Old Notes who do not tender their Old Notes in the
Exchange Offer will continue to hold such Old Notes and will be entitled to all
the rights, and subject to the limitations applicable thereto, under the
Indenture and the Registration Rights Agreement, except for any such rights
under the Registration Rights Agreement that by their terms terminate or cease
to have further effect as a result of the making of this Exchange Offer. See
"Description of the Notes." All untendered Old Notes will continue to be subject
to the restrictions on transfer set forth in the Indenture. The Old Notes may
not be offered, resold, pledged or otherwise transferred, prior to the date that
is two years after the later of July 2,
36
<PAGE> 40
1998 and the last date on which the Company or any "affiliate" (within the
meaning of Rule 144 of the Securities Act) of the Company was the owner of such
Old Note except (i) to the Company, (ii) pursuant to a registration statement
which has been declared effective under the Securities Act, (iii) to Qualified
Institutional Buyers in reliance upon the exemption from the registration
requirements of the Securities Act provided by Rule 144A, (iv) in a transaction
occurring outside the United States to a foreign person, which transaction meets
the requirements of Rule 904 under the Securities Act, (v) in transactions
complying with the provisions of Regulation S under the Securities Act or (vi)
in accordance with another exemption from the registration requirements under
the Securities Act (and based upon an opinion of counsel if the Company so
requests) and, in each case, in accordance with any applicable securities laws
of any State of the United States or any other applicable jurisdiction. To the
extent that Old Notes are tendered and accepted in the Exchange Offer, the
liquidity of the trading market for untendered Old Notes could be adversely
affected.
The Company may in the future seek to acquire untendered Old Notes in the
open market or through privately negotiated transactions, through subsequent
exchange offers or otherwise. The Company intends to make any such acquisitions
of Old Notes in accordance with the applicable requirements of the Exchange Act
and the rules and regulations of the SEC thereunder, including Rule 14e-1, to
the extent applicable. The Company has no present plan to acquire any Old Notes
that are not tendered in the Exchange Offer or to file a registration statement
to permit resales of any Old Notes that are not tendered in the Exchange Offer.
37
<PAGE> 41
USE OF PROCEEDS
The Company will not receive any cash proceeds from the issuance of the
Exchange Notes offered hereby. In consideration for issuing the Exchange Notes
as contemplated in this Prospectus, the Company will receive in exchange Old
Notes in like principal amount. The form and terms of the Exchange Notes are
identical in all material respects to the form and terms of the Old Notes,
except that (i) the offering of the Exchange Notes has been registered under the
Securities Act, (ii) the Exchange Notes will not be subject to transfer
restrictions and (iii) the holders of the Exchange Notes will not be entitled to
registration or other rights under the Registration Rights Agreement including
the payment of Liquidated Damages upon failure by the Company to consummate the
Exchange Offer or the occurrence of certain other events. The Old Notes
surrendered in exchange for Exchange Notes will be retired and canceled and
cannot be reissued. Accordingly, issuance of the Exchange Notes will not result
in a change in the indebtedness of the Company.
38
<PAGE> 42
CAPITALIZATION
The following table sets forth the consolidated capitalization of the
Company as of March 31, 1998 on a (i) historical basis and (ii) as adjusted to
give effect to the Acquisitions, the Offerings giving effect to the exercise of
the over-allotment options granted to the underwriters of PIES and Common Stock
and the initial borrowings under Senior Credit Facility and the application of
the estimated net proceeds therefrom as described under "Use of Proceeds."
This table should be read in conjunction with Tesoro's Consolidated
Financial Statements and the Pro Forma Financial Statements, including the notes
thereto, contained elsewhere in this Prospectus.
<TABLE>
<CAPTION>
MARCH 31, 1998
------------------------------------------
ADJUSTMENTS AS ADJUSTED
TESORO FOR THE FOR THE
HISTORICAL TRANSACTIONS TRANSACTIONS
---------- ------------ ------------
(IN THOUSANDS OF DOLLARS)
<S> <C> <C> <C>
Total debt and other obligations, including current
maturities:
Senior Credit Facility:
Revolver(a)......................................... $ -- $ -- $ --
Tranche A Term Loans(b)............................. -- 50,000 50,000
Tranche B Term Loan................................. -- 100,000 100,000
BHP Note(c)............................................ -- 14,615 14,615
Liability to State of Alaska........................... 61,780 (61,780) --
Other senior debt and obligations...................... 85,938 (65,335) 20,603(d)
The Exchange Notes..................................... -- 298,287 298,287
-------- -------- ----------
Total debt..................................... 147,718 335,787 483,505
Mandatorily Convertible Preferred Stock.................. -- 164,954(e) 164,954
Common stockholders' equity.............................. 339,359 75,937(f) 415,296
-------- -------- ----------
Total capitalization........................... $487,077 $576,678 $1,063,755
======== ======== ==========
</TABLE>
- ---------------
(a) The maximum amount available for the Revolver is $300 million, including
availability of letters of credit.
(b) The Term Loans provide for additional borrowings of up to $50 million in
the aggregate over the first six months following closing of the
Transactions for general corporate purposes (including capital
expenditures).
(c) The amount reflects the scheduled payments of the $50 million, non-interest
bearing BHP Note discounted to present value using a 10% discount rate.
(d) Other debt as adjusted for the Transactions consists primarily of the
Company's obligation to the Department of Energy of approximately $7.9
million and capitalized lease obligations of approximately $9 million for
tugs and barges used in transportation of petroleum products within Hawaii.
The remaining amount consists primarily of obligations of subsidiaries,
none of which are material. See Note I of Notes to Tesoro's Consolidated
Financial Statements.
(e) Includes the impact of the PIES Offering (gross proceeds of $164.9
million).
(f) Includes the impact of the Common Stock Offering (gross proceeds of $91.6
million) and the aftertax charge against earnings for early extinguishment
of debt.
39
<PAGE> 43
PRO FORMA FINANCIAL STATEMENTS
The following unaudited pro forma combined condensed financial statements
give effect to the Transactions including the exercise of the over-allotment
options by the underwriters. The Acquisitions are being accounted for using the
purchase method of accounting. These unaudited pro forma combined condensed
statements have been prepared from, and should be read in conjunction with, the
historical consolidated financial statements and notes thereto, which are
included in or incorporated by reference in this Prospectus.
The Unaudited Pro Forma Combined Condensed Balance Sheet gives effect to
the Transactions as if each had occurred on March 31, 1998. The Unaudited Pro
Forma Condensed Statements of Operations for the year ended December 31, 1997,
and the quarter ended March 31, 1998, give effect to the Transactions as if each
had occurred on January 1, 1997. BHP Hawaii's results of operations, which are
reported on a fiscal year ending May 31, have been adjusted to Tesoro's
reporting periods. The estimates of the fair value of BHP Hawaii's and Shell
Washington's assets and liabilities are based on valuations that are
preliminary. Such valuations may be updated with respect to the Hawaii
Acquisition and the Washington Acquisition, and may change from the amounts
shown herein; however, the Company does not expect such changes to be material.
The unaudited pro forma combined condensed financial statements are intended for
informational purposes and are not necessarily indicative of the future
financial position or future results of the combined companies or of the
financial position or the results of operations that would have actually
occurred had the Acquisitions been in effect as of the date or for the periods
presented. The Unaudited Pro Forma Combined Condensed Statements of Operations
do not reflect any benefits from potential cost savings or revenue enhancements
resulting from the integration of the operations of Tesoro, BHP Hawaii and Shell
Washington (estimated by the Company to be $25 million annually beginning in
1999). Such cost savings and revenue enhancements are discussed in Note (a) to
the Unaudited Pro Forma Combined Condensed Statements of Operations.
40
<PAGE> 44
UNAUDITED PRO FORMA COMBINED CONDENSED BALANCE SHEET
MARCH 31, 1998
<TABLE>
<CAPTION>
HISTORICAL
--------------------------------
BHP SHELL PRO FORMA PRO FORMA
TESORO HAWAII WASHINGTON ADJUSTMENTS COMBINED(L)
-------- -------- ---------- ----------- -----------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
ASSETS
Current Assets:
Cash and cash equivalents............................. $ 2,274 $ 2,519 $ 25 $ (2,544)(a) $ 4,975
2,701(b)
Receivables........................................... 64,518 84,304 12,600 (42,372)(a) 119,050
Inventories........................................... 97,793 71,050 41,305 10,891(c) 221,039
Prepayments and other................................. 7,984 3,919 4,349 (688)(d) 15,564
-------- -------- -------- --------- ----------
Total Current Assets........................... 172,569 161,792 58,279 (32,012) 360,628
-------- -------- -------- --------- ----------
Property, Plant and Equipment:
Refining and marketing................................ 368,183 209,804 372,768 (82,572)(e) 868,183
Exploration and production............................ 311,872 -- -- 311,872
Marine services....................................... 48,201 -- -- 48,201
Corporate............................................. 13,802 -- -- 13,802
-------- -------- -------- --------- ----------
742,058 209,804 372,768 (82,572) 1,242,058
Less accumulated depreciation, depletion and
amortization...................................... 317,645 -- 188,127 (188,127)(e) 317,645
-------- -------- -------- --------- ----------
Net Property, Plant and Equipment................... 424,413 209,804 184,641 105,555(e) 924,413
-------- -------- -------- --------- ----------
Other Assets............................................ 38,447 3,295 8,774 47,271(f) 113,871
17,819(g)
(1,735)(d)
-------- -------- -------- --------- ----------
Total Assets................................... $635,429 $374,891 $251,694 $ 136,898 $1,398,912
======== ======== ======== ========= ==========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Accounts payable...................................... $ 44,275 $ 46,831 $ 9,819 $ (3,553)(a) $ 97,372
Accrued liabilities and current income taxes
payable............................................. 30,253 12,901 4,833 9,886(h) 57,873
Current maturities of long-term debt and other
obligations......................................... 11,428 1,003 -- (9,731)(g) 2,700
-------- -------- -------- --------- ----------
Total Current Liabilities...................... 85,956 60,735 14,652 (3,398) 157,945
-------- -------- -------- --------- ----------
Deferred Income Taxes................................... 31,003 -- 25,523 55,065(j) 111,591
-------- -------- -------- --------- ----------
Other Liabilities....................................... 42,821 29,460 14,412 (18,372)(h) 68,321
-------- -------- -------- --------- ----------
Long-Term Debt and Other Obligations, Less Current
Maturities............................................ 136,290 8,433 -- 336,082(g) 480,805
-------- -------- -------- --------- ----------
Notes Payable to Affiliate.............................. -- 145,000 -- (145,000)(a) --
-------- -------- -------- --------- ----------
Stockholders' Equity:
Preferred Stock....................................... -- -- -- 164,954(b) 164,954
Common Stock.......................................... 4,419 8,208 3 958(b) 5,377
(8,211)(k)
Additional paid-in capital............................ 191,000 52,362 181,011 80,540(b) 271,540
(233,373)(k)
Retained earnings..................................... 147,039 70,693 16,093 (86,786)(k) 141,478
(8,178)(g)
2,617(i)
Treasury stock........................................ (3,099) -- -- (3,099)
-------- -------- -------- --------- ----------
Total Stockholders' Equity..................... 339,359 131,263 197,107 (87,479) 580,250
-------- -------- -------- --------- ----------
Total Liabilities and Stockholders' Equity..... $635,429 $374,891 $251,694 $ 136,898 $1,398,912
======== ======== ======== ========= ==========
</TABLE>
41
<PAGE> 45
NOTES TO UNAUDITED PRO FORMA COMBINED CONDENSED BALANCE SHEET
MARCH 31, 1998
(a) Represents an adjustment to exclude assets and liabilities of BHP Hawaii
and Shell Washington that are not acquired by Tesoro.
(b) Represents an adjustment for the issuance of Mandatorily Convertible
Preferred Stock and Common Stock, the proceeds of which were used to
finance the Transactions.
(c) Represents an adjustment of finished goods inventories to net realizable
value, less an allowance for a normal profit margin, and of raw materials
inventories to replacement cost.
(d) Represents an adjustment to conform the accounting policy for refinery
maintenance costs to that of Tesoro.
(e) Represents an adjustment of property, plant and equipment to fair value.
(f) Represents the excess purchase price over the book value of net assets
acquired.
(g) Represents an adjustment to reflect the $50 million non-interest bearing
BHP Note (discounted at 10%) plus aggregate borrowings of $448 million to
finance the Acquisitions, to refinance existing indebtedness of Tesoro and
to pay related fees, expenses and debt issue costs.
(h) Represents an adjustment to liabilities for certain employee benefits and
for environmental matters taking into effect environmental agreements which
provide for certain environmental indemnifications.
(i) Represents an adjustment to reduce income taxes payable for the tax effect
resulting from charges to earnings related to the refinancing of existing
indebtedness.
(j) Represents an adjustment to record the deferred tax obligations for
differences in book and tax basis for the Washington Acquisition.
(k) Represents the elimination of historical equity of BHP Hawaii and Shell
Washington.
(l) The following are pro forma consolidated balance sheet data excluding the
effects of the Washington Acquisition, but including the effects of the
Offerings and the mandatory special redemption of 50% of the aggregate
principal amount of Notes offered in the Notes Offering:
<TABLE>
<S> <C>
Current assets........................................... $ 302,796
Property, plant and equipment, net....................... $ 639,413
Total assets............................................. $1,002,131
Current liabilities...................................... $ 136,010
Long-term debt and other obligations, less current
maturities............................................. $ 201,479
</TABLE>
42
<PAGE> 46
UNAUDITED PRO FORMA COMBINED CONDENSED STATEMENT OF OPERATIONS
FOR THE YEAR ENDED DECEMBER 31, 1997
<TABLE>
<CAPTION>
HISTORICAL
------------------------------------
BHP SHELL PRO FORMA PRO FORMA
TESORO HAWAII WASHINGTON ADJUSTMENTS(A) COMBINED(L)
-------- ---------- ---------- -------------- -----------
(IN THOUSANDS OF DOLLARS EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C>
Revenues:
Refining and marketing....... $720,868 $ 946,727 $1,089,918 $ $2,757,513
Exploration and production... 84,798 -- -- 84,798
Marine services.............. 132,251 -- -- 132,251
Other income................. 5,543 211 52 5,806
-------- ---------- ---------- --------- ----------
Total Revenues....... 943,460 946,938 1,089,970 2,980,368
-------- ---------- ---------- --------- ----------
Operating Costs and Expenses:
Refining and marketing....... 687,036 882,104 1,038,085 1,500(b) 2,608,725
Exploration and production... 13,230 -- -- 13,230
Marine services.............. 124,725 -- -- 124,725
Depreciation, depletion and
amortization.............. 45,729 13,762 12,715 (3,543)(c) 70,554
1,891(d)
Refinery assets writedown.... 88,813 -- (88,813)(e) --
Goodwill write-off........... -- 30,351 -- (30,351)(e) --
-------- ---------- ---------- --------- ----------
Total Operating Costs
and Expenses....... 870,720 1,015,030 1,050,800 (119,316) 2,817,234
-------- ---------- ---------- --------- ----------
Operating Profit (Loss)........ 72,740 (68,092) 39,170 119,316 163,134
General and Administrative..... (13,588) (25,054)(f) (14,277) (52,919)
Interest Expense, Net of
Capitalized Interest......... (6,699) (8,227) (252) 14,291(g) (52,579)
(51,692)(h)
Interest Income................ 1,597 -- -- 1,597
Other Expense, Net............. (4,930) -- -- (2,894)(i) (7,824)
-------- ---------- ---------- --------- ----------
Earnings Before Income Taxes... 49,120 (101,373) 24,641 79,021 51,409
Income Tax Provision........... 18,435 (27,032) 8,902 19,230(j) 19,535
-------- ---------- ---------- --------- ----------
Earnings Before Extraordinary
Items........................ 30,685 (74,341) 15,739 59,791 31,874
Preferred Dividend............. -- -- -- (11,959)(k) (11,959)
-------- ---------- ---------- --------- ----------
Earnings Before Extraordinary
Items Available for Common
Shares....................... $ 30,685 $ (74,341) $ 15,739 $ 47,832 $ 19,915
======== ========== ========== ========= ==========
Weighted Average Common
Shares -- Basic.............. 26,410 5,750 32,160
======== ========= ==========
Weighted Average Common Shares
and Potentially Dilutive
Common Shares -- Diluted..... 26,868 5,750 32,618
======== ========= ==========
Earnings Before Extraordinary
Items:
Per Share -- Basic........... $ 1.16 $ 0.62
======== ==========
Per Share -- Diluted......... $ 1.14 $ 0.61
======== ==========
</TABLE>
43
<PAGE> 47
UNAUDITED PRO FORMA COMBINED CONDENSED STATEMENT OF OPERATIONS
FOR THE THREE MONTHS ENDED MARCH 31, 1998
<TABLE>
<CAPTION>
HISTORICAL
---------------------------------
BHP SHELL PRO FORMA PRO FORMA
TESORO HAWAII WASHINGTON ADJUSTMENTS(A) COMBINED(L)
-------- --------- ---------- -------------- -----------
(IN THOUSANDS OF DOLLARS EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C>
Revenues:
Refining and marketing.......... $140,213 $ 210,447 $201,431 $ $ 552,091
Exploration and production...... 22,222 -- 22,222
Marine services................. 32,818 -- 32,818
Other income.................... 786 (3) 30 813
-------- --------- -------- --------- ---------
Total Revenues.......... 196,039 210,444 201,461 607,944
-------- --------- -------- --------- ---------
Operating Costs and Expenses:
Refining and marketing.......... 130,720 191,642 195,685 1,500(b) 519,547
Exploration and production...... 3,925 -- -- 3,925
Marine services................. 30,597 -- -- 30,597
Depreciation, depletion and
amortization................. 12,944 -- 3,703 2,030(c) 19,150
473(d)
Refinery assets writedown....... -- 125,049 -- (125,049)(e) --
-------- --------- -------- --------- ---------
Total Operating Costs
and Expenses.......... 178,186 316,691 199,388 (121,046) 573,219
-------- --------- -------- --------- ---------
Operating Profit (Loss)........... 17,853 (106,247) 2,073 121,046 34,725
General and Administrative........ (3,372) (5,139) (2,512) (11,023)
Interest Expense, Net of
Capitalized Interest............ (2,665) (2,436) (10) 4,708(g) (13,326)
(12,923)(h)
Interest Income................... 108 -- -- 108
Other Expense, Net................ (1,034) -- -- (703)(i) (1,737)
-------- --------- -------- --------- ---------
Earnings Before Income Taxes...... 10,890 (113,822) (449) 112,128 8,747
Income Tax Provision.............. 4,831 (33,676) (80) 32,774(j) 3,849
-------- --------- -------- --------- ---------
Earnings Before Extraordinary
Items........................... 6,059 (80,146) (369) 79,354 4,898
Preferred Dividend................ -- -- -- (2,990)(k) (2,990)
-------- --------- -------- --------- ---------
Earnings Before Extraordinary
Items Available for Common
Shares.......................... $ 6,059 $ (80,146) $ (369) $ 76,364 $ 1,908
======== ========= ======== ========= =========
Weighted Average Common Shares
Basic........................... 26,309 5,750 32,059
======== ========= =========
Weighted Average Common Shares and
Potentially Dilutive Common
Shares -- Diluted............... 26,789 5,750 32,539
======== ========= =========
Earnings Before Extraordinary
Items:
Per Share -- Basic.............. $ 0.23 $ 0.06
======== =========
Per Share -- Diluted............ $ 0.23 $ 0.06
======== =========
</TABLE>
44
<PAGE> 48
NOTES TO UNAUDITED PRO FORMA COMBINED CONDENSED STATEMENTS OF OPERATIONS
FOR THE YEAR ENDED DECEMBER 31, 1997 AND THREE MONTHS ENDED MARCH 31, 1998
(a) The Unaudited Pro Forma Combined Condensed Statements of Operations do not
give any effect to potential cost savings or revenue enhancements, which
the Company believes will result from integrating the operations of the
companies after the Acquisitions. Management expects to begin to realize
such projected cost savings and revenue enhancements in the fourth quarter
of 1998. The full annual impact of such projected cost savings and revenue
enhancements is expected to be achieved in the fiscal year ending December
31, 1999, and is estimated to be approximately $25 million annually
beginning in 1999.
(b) Represents an adjustment for a Tesoro contract termination.
(c) Represents an adjustment in depreciation expense due to the change in
property, plant and equipment to fair value. Pro forma depreciation is
calculated on the straight-line method over estimated useful lives of 28
years for refineries and five to ten years for machinery, equipment and
buildings.
(d) Represents the amortization of goodwill over 25 years.
(e) Represents elimination of the charge for asset and goodwill impairment
recognized in the BHP Hawaii historical financial statements.
(f) Includes BHP Hawaii employee bonuses of $4 million in the year ended
December 31, 1997, which were awarded based upon the performance of BHP
operations that are not to be acquired by Tesoro.
(g) Represents elimination of interest on BHP Hawaii's obligations that will
not be assumed by Tesoro and the elimination of interest on Tesoro's
obligations that will be refinanced.
(h) Represents additional interest under the Revolver, the Term Loans, the
Notes and accretion of the $50 million non-interest bearing BHP Note. See
"Description of Other Indebtedness -- Other Indebtedness."
(i) Represents the amortization of debt issuance costs related to the Revolver,
the Term Loans and the Notes.
(j) Represents the tax effect of the adjustments above, excluding amortization
of goodwill for the Washington Acquisition.
(k) Represents a 7.25% annual dividend rate on the Mandatorily Convertible
Preferred Stock.
(l) The following are pro forma consolidated results of operations excluding
the effects of the Washington Acquisition, but including the effects of the
Offerings and the mandatory special redemption of 50% of the aggregate
principal amount of the Notes offered in the Notes Offering:
<TABLE>
<CAPTION>
THREE MONTHS
YEAR ENDED ENDED
DECEMBER 31, MARCH 31,
1997 1998
------------ ------------
<S> <C> <C>
Revenues........................................ $1,890,398 $406,483
Expenses........................................ $1,846,127 $394,239
Earnings before income taxes.................... $ 44,271 $ 12,244
Income tax provision............................ $ 16,216 $ 5,388
Earnings before extraordinary items............. $ 28,055 $ 6,856
</TABLE>
45
<PAGE> 49
SELECTED HISTORICAL FINANCIAL DATA
The following table sets forth certain selected historical consolidated
financial information for Tesoro based upon its historical financial statements
included in or incorporated by reference in this Prospectus. Separate financial
statements of the subsidiary Guarantors are not included herein because the
subsidiary Guarantors are jointly and severally liable on the Notes and the
aggregate net assets, earnings and equity of such Guarantors are substantially
equivalent to the net assets, earnings and equity of the parent on a
consolidated basis.
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
--------------------------------------------------- -----------------
1993 1994 1995 1996 1997 1997 1998
------- ------- --------- --------- ------- ------- -------
(IN MILLIONS EXCEPT PER SHARE AMOUNTS AND RATIOS)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENTS OF OPERATIONS DATA
Total revenues................................... $ 830.4 $ 871.9 $ 1,002.9 $ 1,039.8 $ 943.4 $ 234.9 $ 196.0
Total segment operating profit(a)(b)............. $ 52.3 $ 64.4 $ 105.9 $ 144.8 $ 72.7 $ 15.0 $ 17.9
Net earnings..................................... $ 17.0 $ 15.7 $ 54.6 $ 74.5 $ 30.7 $ 6.1 $ 6.1
Net earnings applicable to common stock.......... $ 7.8 $ 13.0 $ 54.6 $ 74.5 $ 30.7 $ 6.1 $ 6.1
Earnings per share -- basic(c)................... $ 0.55 $ 0.58 $ 2.22 $ 2.87 $ 1.16 $ 0.23 $ 0.23
Earnings per share -- diluted(c)................. $ 0.54 $ 0.56 $ 2.18 $ 2.81 $ 1.14 $ 0.23 $ 0.23
OTHER DATA
EBITDA, as reported(d):
Refining and marketing......................... $ 25.5 $ 12.8 $ 12.6 $ 18.5 $ 33.2 $ 3.2 $ 9.5
Exploration and production..................... 51.8 88.6 139.2 159.6 77.2 22.1 19.0
Marine services................................ (3.2) (2.0) (4.1) 7.3 8.0 1.3 2.4
------- ------- --------- --------- ------- ------- -------
Total segment EBITDA..................... 74.1 99.4 147.7 185.4 118.4 26.6 30.9
Corporate and unallocated...................... (18.3) (18.6) (22.3) (13.4) (16.2) (3.7) (4.1)
------- ------- --------- --------- ------- ------- -------
Total consolidated EBITDA................ $ 55.8 $ 80.8 $ 125.4 $ 172.0 $ 102.2 $ 22.9 $ 26.8
======= ======= ========= ========= ======= ======= =======
Normalized EBITDA(e):
Refining and marketing......................... $ 25.5 $ 7.0 $ 13.0 $ 19.3 $ 33.2 $ 3.2 $ 9.5
Exploration and production..................... 32.1 49.7 58.8 70.0 73.2 20.5 19.0
Marine services................................ (3.2) (0.1) (3.3) 7.3 8.0 1.3 2.4
------- ------- --------- --------- ------- ------- -------
Total segment EBITDA..................... 54.4 56.6 68.5 96.6 114.4 25.0 30.9
Corporate and unallocated...................... (19.7) (18.5) (18.5) (14.7) (16.2) ( 3.7) ( 4.1)
------- ------- --------- --------- ------- ------- -------
Total consolidated EBITDA................ $ 34.7 $ 38.1 $ 50.0 $ 81.9 $ 98.2 $ 21.3 $ 26.8
======= ======= ========= ========= ======= ======= =======
Capital expenditures
Refining and marketing......................... $ 7.1 $ 32.0 $ 9.3 $ 11.1 $ 43.9 $ 2.9 $ 2.0
Exploration and production..................... 29.3 65.6 53.4 66.6 92.9 11.0 20.5
Marine services................................ 0.3 0.2 0.4 6.9 9.4 2.2 1.2
Other.......................................... 0.8 1.8 0.8 0.4 1.3 0.2 0.1
------- ------- --------- --------- ------- ------- -------
Total capital expenditures............... $ 37.5 $ 99.6 $ 63.9 $ 85.0 $ 147.5 $ 16.3 $ 23.8
======= ======= ========= ========= ======= ======= =======
BALANCE SHEET DATA
Working capital.................................. $ 124.5 $ 85.9 $ 77.5 $ 99.5 $ 74.3 $ 104.8 $ 86.7
Property, plant and equipment, net............... $ 213.2 $ 273.3 $ 261.7 $ 316.5 $ 413.8 $ 320.7 $ 424.4
Total assets..................................... $ 434.5 $ 484.4 $ 519.2 $ 582.6 $ 627.8 $ 552.0 $ 635.4
Total long-term debt and other obligations(f).... $ 185.5 $ 199.6 $ 164.5 $ 89.3 $ 132.3 $ 89.3 $ 147.7
Redeemable preferred stock(f).................... $ 78.1 $ -- $ -- $ -- $ -- $ -- $ --
Stockholders' equity(f).......................... $ 58.5 $ 160.7 $ 216.5 $ 304.1 $ 333.0 $ 310.4 $ 339.4
</TABLE>
- ---------------
(a) Results for the years 1993, 1994, 1995 and 1996 include revenues from
above-market pricing provisions of a natural gas contract which was
terminated effective October 1, 1996. Operating profit included $20
million, $39 million, $47 million and $25 million in the years 1993, 1994,
1995 and 1996, respectively, from the excess of these contract prices over
spot market prices. Upon termination of the contract in 1996, the
Exploration and Production segment also recorded a non-recurring increase
in other income and operating profit of $60 million in connection with the
settlement of the contract. In the year 1995, the Exploration and
Production segment recorded other income and operating profit of $33
million from the sale of certain interests in the Bob West Field. See Notes
C and D of Notes to Tesoro's Consolidated Financial Statements.
(b) Segment operating profit equals gross operating revenues, gains and losses
on asset sales and other income less applicable segment costs of sales,
operating expenses, depreciation, depletion and other items. Income taxes,
interest expense and corporate general and administrative expenses are not
included in determining operating profit.
(c) Earnings per share amounts for periods prior to the quarter ended December
31, 1997 have been restated, where appropriate, to conform with the
requirements of Statement of Financial Accounting Standard ("SFAS") No.
128. See Note A of Notes to Tesoro's Consolidated Financial Statements.
(d) EBITDA represents earnings before extraordinary item, interest expense,
income taxes and depreciation, depletion and amortization. Segment EBITDA
represents operating profit before 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.
EBITDA is not a calculation based upon GAAP however, the amounts included
in the EBITDA calculation are derived from amounts included in Tesoro's
46
<PAGE> 50
Consolidated Financial Statements. In addition, EBITDA should not be
considered as an alternative to net earnings or operating profit, as an
indication of the operating performance of the Company or an alternative to
operating cash flow as a measure of liquidity. EBITDA is not necessarily
comparable to similarly titled items of other companies.
(e) Normalized EBITDA is EBITDA, as defined in (d) above, excluding the impact
of the above-market natural gas contract with Tennessee Gas and other
significant items which affect the comparability between the periods
presented. The following items have been excluded from EBITDA, as reported,
to generate normalized EBITDA for each segment (in millions):
<TABLE>
<CAPTION>
THREE
MONTHS
ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
----------------------------------------- ------------
1993 1994 1995 1996 1997 1997 1998
----- ----- ----- ----- ----- ---- ----
<S> <C> <C> <C> <C> <C> <C> <C>
Refining and Marketing.................. $ -- $ 5.8 $(0.4) $(0.8) $ -- $-- $--
----- ----- ----- ----- ---- ---- ---
Exploration and Production:
Excess of contract prices over spot
market prices....................... 19.7 38.9 47.1 24.6 -- -- --
Income from settlement of a natural
gas contract........................ -- -- -- 60.0 -- -- --
Gain on sale of asset................. -- -- 33.5 -- -- -- --
Other non-recurring income (charges),
net................................. -- -- (0.2) 5.0 4.0 1.6 --
----- ----- ----- ----- ---- ---- ---
Total Exploration and Production.... 19.7 38.9 80.4 89.6 4.0 1.6 --
----- ----- ----- ----- ---- ---- ---
Marine Services......................... -- (1.9) (0.8) -- -- -- --
----- ----- ----- ----- ---- ---- ---
Corporate and Unallocated............... 1.4 (0.1) (3.8) 1.3 -- -- --
----- ----- ----- ----- ---- ---- ---
Total Adjustments................... $21.1 $42.7 $75.4 $90.1 $4.0 $1.6 $--
===== ===== ===== ===== ==== ==== ===
</TABLE>
For further information regarding these significant items, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations."
(f) In 1994, the Company restructured its outstanding debt and preferred stock
by completing a recapitalization and equity offering.
47
<PAGE> 51
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
The following analysis of the financial condition and results of operations
of Tesoro should be read in conjunction with Tesoro's Consolidated Financial
Statements, including the notes thereto, included elsewhere in this Prospectus.
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 18 for discussion
of the factors which could cause actual results to differ materially from those
projected in such statements.
GENERAL
The Company's strategy is to (i) maximize return on capital employed and
increase the competitiveness of each of its business units by reducing costs,
increasing operating efficiencies and optimizing existing assets and (ii) expand
its overall market presence through a combination of internal growth initiatives
and selective acquisitions which are both accretive to earnings and provide
significant operational synergies. In 1998, the Company plans to further improve
profitability in the Refining and Marketing segment by enhancing processing
capabilities, strengthening marketing channels and improving supply and
transportation functions. In the Exploration and Production segment, the
strategy includes evaluating ways in which the Company can continue to diversify
its oil and gas reserve base through both acquisitions and the drill bit and
enhanced technical capabilities. The Company has made significant progress in
diversifying its U.S. operations to areas other than the Bob West Field and has
taken steps to begin serving emerging markets in South America. Improved
profitability has positioned the Marine Services segment to participate in the
consolidation of the industry by pursuing opportunities for expansion, as well
as optimizing existing operations.
In May 1998, Tesoro acquired the Hawaiian refining and marketing assets of
two subsidiaries of BHP and entered into an agreement to acquire the Washington
Refinery and related refining assets from a subsidiary of Shell. The
Acquisitions are expected to triple Tesoro's annual revenues and significantly
increase the scope of Tesoro's refining and marketing operations. Tesoro expects
that the results of the Acquisitions will be accretive to earnings and cash
flows beginning in 1999. The impact of the Acquisitions on earnings and cash
flow may be neutral in 1998 primarily due to the mid-year timing of the
Acquisitions and a scheduled maintenance turnaround at the Hawaii Refinery to
begin in the summer of 1998. The Company will continue to pursue other
opportunities that are operationally and geographically complementary with its
asset base.
As part of the Company's long-term strategy, growth initiatives are planned
in 1998 with a capital budget of $195 million, excluding amounts required to
fund the Acquisitions and capital expenditures related to the Hawaii and
Washington operations following such acquisitions which are projected to be
approximately $15 to $20 million in 1998. The $195 million capital budget
represents an increase of 33% over 1997 capital expenditures. Approximately 71%
of the 1998 capital budget is directed toward increased drilling and other
related exploration costs, both in Bolivia and the U.S. Another 25% is planned
for downstream operations, primarily improvements in the Alaska marketing
operations. The remaining 4% of the 1998 capital budget is dedicated to
corporate expenditures, primarily upgrading information systems.
The Company operates in an environment where its results and cash flows are
sensitive to volatile changes in energy prices. Major shifts in the cost of
crude oil used for refinery feedstocks and the price of refined products can
result in a change in margin from the Refining and Marketing operations, as
prices received for refined products may or may not keep pace with changes in
crude oil costs. These energy prices, together with volume levels, also
determine the carrying value of crude oil and refined product inventory. The
Company uses the last-in, first-out method of accounting for inventories of
crude oil and U.S. wholesale refined products in its Refining and Marketing
segment. This method results in inventory carrying amounts that are less likely
to represent current values and in costs of sales which more closely represent
current costs. Similarly, changes in natural gas, condensate and oil prices
impact revenues and the present value of estimated future net revenues and cash
flows from the Company's Exploration and Production operations. Tesoro may
increase or decrease its natural gas production in response to market
conditions. The carrying value of oil and gas assets may be subject to noncash
write-downs based on changes in natural gas prices and other
48
<PAGE> 52
determining factors. Changes in natural gas prices also influence the level of
drilling activity in the Gulf of Mexico. The Company's Marine Services
operation, whose customers include offshore drilling contractors and related
industries, could be impacted by significant fluctuations in natural gas prices.
The Company's Marine Services segment uses the first-in, first-out method of
accounting for inventories of fuels. Changes in fuel prices can significantly
impact inventory valuations and costs of sales in this segment.
RESULTS OF OPERATIONS
This "Results of Operations" section reflects only the results of
operations of Tesoro for periods prior to the consummation of the Transactions
and does not include any financial information concerning BHP Hawaii and Shell
Washington.
SUMMARY
Tesoro's net earnings of $6.1 million, or $0.23 per share, for the three
months ended March 31, 1998 ("1998 Quarter") compare with net earnings of $6.1
million, or $0.23 per share, for the three months ended March 31, 1997 ("1997
Quarter"). Improved refined product margins combined with higher sales volumes
in the Company's Refining and Marketing segment and Marine Services segment
during the 1998 Quarter were offset by lower natural gas prices in the Company's
Exploration and Production segment.
Tesoro's net earnings for the year 1997 were $30.7 million ($1.16 per basic
share, $1.14 per diluted share) compared to $74.5 million ($2.87 per basic
share, $2.81 per diluted share) in the year 1996 and $54.6 million ($2.22 per
basic share, $2.18 per diluted share) in the year 1995. In the years 1996 and
1995, Tesoro incurred noncash aftertax extraordinary losses of $2.3 million and
$2.9 million, respectively, for early extinguishments of debt. Earnings before
extraordinary losses amounted to $76.8 million ($2.96 per basic share, $2.90 per
diluted share) and $57.5 million ($2.34 per basic share, $2.29 per diluted
share) in the years 1996 and 1995, respectively. Results for the years 1996 and
1995 included revenues from sales of natural gas at above-market prices under a
contract with Tennessee Gas Pipeline Company ("Tennessee Gas") which was
terminated effective October 1, 1996. Results of operations in 1997 and future
years no longer benefit from above-market revenues under this contract.
Significant items, including the impact of the Tennessee Gas contract, which
affect the comparability between results of operations are highlighted in the
table below (in millions except per share amounts):
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
------------------------- ----------------
1995 1996 1997 1997 1998
------- ------ ------ ------ -------
<S> <C> <C> <C> <C> <C>
Net Earnings as Reported..................... $ 54.6 $74.5 $30.7 $ 6.1 $ 6.1
Extraordinary Loss on Debt Extinguishments,
Net of Income Tax Benefit.................. 2.9 2.3 -- -- --
------ ----- ----- ----- ------
Earnings Before Extraordinary Item........... 57.5 76.8 30.7 6.1 6.1
------ ----- ----- ----- ------
Significant Items Affecting Comparability,
Pretax:
Income from settlement of a natural gas
contract................................ -- 60.0 -- -- --
Operating profit from excess of contract
prices over spot market prices.......... 47.1 24.6 -- -- --
Other, including gain on sale and other
income and expense items................ 28.3 5.5 4.0 1.6 --
------ ----- ----- ----- ------
Total Significant Items, Pretax......... 75.4 90.1 4.0 1.6 --
Income Tax Effect....................... -- 27.2 1.2 0.5 --
------ ----- ----- ----- ------
Total Significant Items, Aftertax....... 75.4 62.9 2.8 1.1 --
------ ----- ----- ----- ------
Net Earnings (Loss) Excluding Significant
Items and Extraordinary Item............... $(17.9) $13.9 $27.9 $ 5.0 $ 6.1
====== ===== ===== ===== ======
</TABLE>
49
<PAGE> 53
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
------------------------- ----------------
1995 1996 1997 1997 1998
------- ------ ------ ------ -------
<S> <C> <C> <C> <C> <C>
Earnings Per Share -- Basic:
As reported................................ $ 2.22 $2.87 $1.16 $0.23 $ 0.23
Extraordinary loss......................... (0.12) (0.09) -- -- --
Impact of contract prices over spot market
prices and settlement income............ 1.92 2.28 -- -- --
Effect of other significant items.......... 1.15 0.15 0.10 0.04 --
------ ----- ----- ----- ------
Excluding significant items and
extraordinary item...................... $(0.73) $0.53 $1.06 $0.19 $ 0.23
====== ===== ===== ===== ======
Earnings Per Share -- Diluted:
As reported................................ $ 2.18 $2.81 $1.14 $0.23 $ 0.23
Extraordinary loss......................... (0.11) (0.09) -- -- --
Impact of contract prices over spot market
prices and settlement income............ 1.88 2.23 -- -- --
Effect of other significant items.......... 1.14 0.14 0.10 0.04 --
------ ----- ----- ----- ------
Excluding significant items and
extraordinary item...................... $(0.73) $0.53 $1.04 $0.19 $ 0.23
====== ===== ===== ===== ======
</TABLE>
As shown above, excluding the significant items affecting comparability,
Tesoro's net earnings would have been $27.9 million ($1.06 per basic share,
$1.04 per diluted share) in the year 1997, as compared to net earnings of $13.9
million ($0.53 per basic and diluted share) in the year 1996 and a net loss of
$17.9 million ($0.73 per basic and diluted share) in the year 1995. The
resulting $14 million increase in net earnings in the year 1997 was primarily
attributable to better refined product margins, higher spot market natural gas
prices and lower corporate interest expense.
When comparing the year 1996 to 1995, after excluding significant items,
the improvement in net earnings of approximately $32 million was primarily
attributable to improvements within Tesoro's Refining and Marketing and Marine
Services segments together with reduced general and administrative expenses and
interest expense. These improvements were partially offset by an increase in
Tesoro's total effective tax rate in the year 1996 as earnings subject to U.S.
taxes exceeded available net operating loss and tax credit carryforwards.
A discussion and analysis of the factors contributing to these results are
presented below. The accompanying consolidated financial statements and related
footnotes, together with the following information, are intended to provide
shareholders and other investors with a reasonable basis for assessing Tesoro's
operations, but should not serve as the sole criterion for predicting the future
performance of Tesoro.
50
<PAGE> 54
REFINING AND MARKETING
The following table summarizes the Refining and Marketing segment's results
of operations for the years ended December 31, 1995, 1996 and 1997 and the three
months ended March 31, 1997 and 1998.
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
--------------------------- -----------------
1995 1996 1997 1997 1998
------- ------- ------- ------- -------
(DOLLARS IN MILLIONS EXCEPT PER BARREL AMOUNTS)
<S> <C> <C> <C> <C> <C>
GROSS OPERATING REVENUES
Total refined products..................... $ 664.5 $ 620.8 $ 643.7 $ 155.8 $ 122.7
Other, primarily crude oil resales and
merchandise............................. 106.5 124.6 77.2 18.6 17.5
------- ------- ------- ------- -------
Total Gross Operating Revenues..... $ 771.0 $ 745.4 $ 720.9 $ 174.4 $ 140.2
======= ======= ======= ======= =======
TOTAL OPERATING PROFIT
Gross margin:
Refinery(a)............................. $ 63.5 $ 74.6 $ 93.3 $ 18.3 $ 24.0
Non-refinery(b)......................... 34.1 32.7 36.6 6.4 9.7
------- ------- ------- ------- -------
Total gross margin................. 97.6 107.3 129.9 24.7 33.7
Operating expenses......................... 84.7 87.9 96.0 21.5 24.2
Depreciation and amortization.............. 11.9 12.5 12.7 3.1 3.0
Loss on sales of assets and other.......... 0.3 0.9 0.7 -- --
------- ------- ------- ------- -------
Total Operating Profit............. $ 0.7 $ 6.0 $ 20.5 $ 0.1 $ 6.5
======= ======= ======= ======= =======
CAPITAL EXPENDITURES......................... $ 9.3 $ 11.1 $ 43.9 $ 2.9 $ 2.0
======= ======= ======= ======= =======
REFINERY PRODUCT SPREAD ($/barrel)........... $ 3.44 $ 4.29 $ 5.09 $ 4.13 $ 4.75
======= ======= ======= ======= =======
TOTAL SEGMENT PRODUCT SALES (average bpd)(c)
Gasoline................................... 24,526 17,427 17,393 16,738 14,495
Middle distillates......................... 37,988 29,651 30,576 26,253 32,875
Heavy oils and residual products........... 14,787 15,089 17,929 17,890 18,308
------- ------- ------- ------- -------
Total Product Sales................ 77,301 62,167 65,898 60,881 65,678
======= ======= ======= ======= =======
TOTAL SEGMENT PRODUCT SALES PRICES($/barrel)
Gasoline................................... $ 28.21 $ 32.72 $ 33.71 $ 33.64 $ 28.52
Middle distillates......................... $ 24.40 $ 29.01 $ 28.36 $ 32.09 $ 22.33
Heavy oils and residual products........... $ 13.66 $ 17.61 $ 17.30 $ 18.19 $ 11.32
TOTAL SEGMENT GROSS MARGINS ON PRODUCT SALES
($/barrel)(d)
Average sales price........................ $ 23.55 $ 27.28 $ 26.76 $ 28.43 $ 20.65
Average costs of sales..................... 20.53 23.15 21.92 24.63 15.58
------- ------- ------- ------- -------
Gross Margin....................... $ 3.02 $ 4.13 $ 4.84 $ 3.80 $ 5.07
======= ======= ======= ======= =======
</TABLE>
- ---------------
(a) Represents throughput at the Alaska Refinery times refinery product spread.
(b) Non-refinery margin includes margins on products purchased and resold,
margins on products sold in markets outside of Alaska, intrasegment
pipeline revenues, retail margins, and adjustments due to selling a volume
and mix of products that is different than actual volumes manufactured.
(c) Sources of total product sales include products manufactured at the Alaska
Refinery, products drawn from inventory balances and products purchased
from third parties. Tesoro's purchases of refined products for resale
averaged approximately 25,500, 11,600 and 11,300 bpd in the years 1995,
1996 and
51
<PAGE> 55
1997, respectively, and 11,500 and 11,700 bpd in the three months ended
March 31, 1997 and 1998, respectively.
(d) Gross margins on total product sales include margins on sales of purchased
products, together with the effect of changes in inventories.
Three Months Ended March 31, 1998 Compared to Three Months Ended March 31,
1997
The Refining and Marketing segment's operating profit of $6.5 million in
the 1998 Quarter increased $6.4 million from operating profit of $0.1 million in
the 1997 Quarter. The improvement in results from Refining and Marketing was due
to a combination of factors, including improved refined product yields, higher
throughput volumes at the refinery and increased sales within the segment's core
Alaska market, all of which contributed to improved refinery margins. The 1998
Quarter benefitted from an expansion completed in October 1997 of the Alaska
Refinery's hydrocracker unit, which increased the unit's capacity by
approximately 25% and enables the Company to produce more jet fuel, a product in
short supply in Alaska. The expansion, together with the addition of a new,
high-yield jet fuel hydrocracker catalyst, began to favorably impact this
segment's results in the fourth quarter of 1997.
During the 1998 Quarter, throughput at the Alaska Refinery increased by
7,000 bpd, a 14% increase over the 1997 Quarter. Production of middle
distillates increased by 4,300 bpd (a 21% increase over the 1997 Quarter) and
production of gasoline increased by 2,300 bpd (an 18% increase over the 1997
Quarter). Product sales volumes increased by 8% over the 1997 Quarter, which
included a 15% increase within the core Alaska market. The increase in sales in
Alaska was mainly due to a long-term retail capital spending program, primarily
focused in the Anchorage area, which was initiated in 1997. The improved product
slate and marketing efforts contributed to an increase in the Alaska Refinery's
product spread to $4.75 per barrel in the 1998 Quarter, compared to $4.13 per
barrel in the 1997 Quarter, reflecting a 39% decrease in the Company's per
barrel feedstock cost with a 30% decline in per barrel yield value.
Revenues from sales of refined products in the Refining and Marketing
segment decreased during the 1998 Quarter due to a 27% decline in average sales
prices partly offset by the 8% increase in sales volumes. Other revenues
included crude oil resales of $10.5 million in the 1998 Quarter and $10.7
million in the 1997 Quarter. Costs of sales decreased in the 1998 Quarter due to
lower feedstock prices. Margins from non-refinery activities increased to $9.7
million in the 1998 Quarter due primarily to a 14% increase in retail volumes
and improved margins on products sold outside Alaska. Operating expenses were
higher in the 1998 Quarter due to increased marketing costs.
The Company's initiatives to enhance its product slate and sell more
products within Alaska, as discussed above, have improved the fundamental
earnings potential of this segment. Certain of these initiatives, such as the
hydrocracker expansion, were completed in the fourth quarter of 1997. Future
quarters will continue to benefit from the impact of these initiatives. Future
profitability of this segment, however, will continue to be influenced by market
conditions, particularly as these conditions influence costs of crude oil
relative to prices received for sales in refined products, and other additional
factors that are beyond the control of the Company. As previously discussed, the
revenues and scope of the Refining and Marketing segment will be significantly
increased upon the consummations of the Hawaii Acquisition and Washington
Acquisition.
Year Ended December 31, 1997 Compared to Year Ended December 31, 1996
The Refining and Marketing segment's operating profit of $20.5 million in
1997 increased $14.5 million from operating profit of $6.0 million in 1996. The
improvement in results from Refining and Marketing has been due in part to
Tesoro's initiatives to enhance its product slate, improve efficiencies and sell
a larger portion of the Alaska Refinery's production within the core Alaska
market. In these regards, in early October 1997, Tesoro completed an expansion
of the Alaska Refinery's hydrocracker unit which began to favorably impact this
segment's results in the fourth quarter of 1997. With respect to crude oil
supply, during 1997, Tesoro negotiated contracts to purchase the remaining Cook
Inlet crude oil production available for sale and, in October 1997, began
purchasing approximately 25,000 bpd of Cook Inlet crude oil in addition to the
approximate 9,000 bpd under previously existing contracts. Substantially all of
the contracts for purchases of
52
<PAGE> 56
Cook Inlet crude oil are for various periods extending through December 1998. As
part of a three-year, $50 million Alaskan retail marketing expansion program
initiated in 1997, Tesoro built two new retail stations, remodeled three
stations, bought two stations and closed two uneconomic stations. At year-end
1997, the total number of retail stations selling Tesoro's gasoline totaled 222
as compared to 206 in 1996. Of these stations, 30 are located in the Pacific
Northwest, compared to 18 at year-end 1996.
During 1997, Tesoro's production of refined products increased in total by
5% due to higher throughput levels at the Alaska Refinery. The operational
changes, previously discussed, resulted in an 8% increase in the production of
middle distillates, primarily jet fuel, while gasoline production remained flat.
Production of heavy oils and residual products increased by 7% in 1997. The
improved product slate, which better matches Tesoro's product supply with demand
in Alaska, reflected the change of a hydrocracker catalyst in late 1996 and the
hydrocracker expansion and catalyst change in late 1997. Tesoro's sales of
refined products within Alaska increased by 6% in 1997 contributing to higher
product margins. The improved product slate and marketing efforts, together with
generally favorable industry conditions, resulted in an increase in Tesoro's
refinery spread to $5.09 per barrel in 1997, compared to $4.29 per barrel in
1996, reflecting a 10% decrease in Tesoro's per barrel feedstock cost with only
a 5% decline in per barrel yield value. Both years included scheduled 30-day
maintenance turnarounds.
Revenues from sales of refined products in Tesoro's Refining and Marketing
segment increased during 1997 due primarily to a 6% increase in sales volumes,
partially offset by slightly lower average sales prices. Total refined product
sales averaged 65,898 bpd in 1997 as compared to 62,167 bpd in 1996. Other
revenues, which included crude oil resales of $44.4 million in 1997 and $93.8
million in 1996, declined due to lower sales volumes and prices. Tesoro had less
crude oil available for resale in 1997 as throughput at the Alaska Refinery
increased by 2,721 bpd, or 6%, from 1996 and fewer spot purchases of crude oil
were made. Export sales of refined products, including sales to the Russian Far
East, amounted to $16.1 million in 1997 compared to $22.0 million in 1996. Costs
of sales decreased in 1997 due to lower spot purchases of crude oil and lower
prices. Margins from non-refinery activities increased to $36.6 million in 1997
due primarily to higher retail sales and improved margins on products sold
outside of Alaska. Operating expenses increased in 1997 due primarily to higher
employee costs, professional fees and marketing expenses.
Year Ended December 31, 1996 Compared to Year Ended December 31, 1995
Results from Tesoro's Refining and Marketing segment improved during 1996
with operating profit of $6.0 million, compared to operating profit of $0.7
million in 1995. This improvement was achieved during a year when the industry
was facing rapidly rising prices in the crude oil market. In addition, Tesoro's
production level at the Alaska Refinery was reduced in September 1996 for a
scheduled 30-day maintenance turnaround. Despite these factors, Tesoro was able
to achieve a refinery product spread of $4.29 per barrel for 1996, compared to
$3.44 per barrel in 1995. Tesoro's results were helped by its initiatives to
control costs, improve the Alaska Refinery's product slate and expand the
marketing program for its refined products. Tesoro's average refined product
yield value per barrel increased by 19% in 1996, while Tesoro's feedstock costs
per barrel increased by 17%.
During 1996, Tesoro's production of refined products declined in total by
6%, which included the impact of the scheduled maintenance period. Of this
decline, gasoline production decreased by 11% and middle distillates decreased
by only 3%. These reductions reflected the change of a hydrocracker catalyst
during the maintenance period, which allows for increased production of jet fuel
and reduced production of gasoline beginning in the fourth quarter of 1996,
which better matches Tesoro's product supply with demand in Alaska.
During 1996, Tesoro's marketing efforts added 31 stations in Alaska and
eight stations in the Pacific Northwest, bringing the total to 188 branded,
unbranded and Company-operated stations in Alaska and 18 branded stations in the
Pacific Northwest at year-end 1996. Two uneconomic stations in these areas were
closed in 1996. In addition, Tesoro began producing and marketing liquid
asphalt, which is a seasonal product in Alaska. Export sales of refined
products, including sales to the Russian Far East, amounted to $22.0 million in
1996 and $18.5 million in 1995.
Revenues from sales of refined products in Tesoro's Refining and Marketing
segment decreased in 1996 due primarily to a 20% decline in sales volumes,
partially offset by a 16% increase in average sales prices. Total
53
<PAGE> 57
refined product sales averaged 62,167 bpd in 1996 as compared to 77,301 bpd in
1995. This decline reflected the lower production volumes and Tesoro's
withdrawal from certain U.S. West Coast markets during 1996, which also reduced
Tesoro's purchases from other refiners and suppliers to 11,600 bpd in 1996 as
compared to 25,500 bpd in 1995. One of the U.S. West Coast facilities was sold
in 1996 resulting in a loss of $0.8 million. Sales of previously purchased crude
oil increased to $93.8 million in 1996, compared to $75.8 million in 1995, due
primarily to higher crude oil prices and in part due to sales of excess crude
supply volumes during the maintenance period. Costs of sales decreased in 1996
due to lower volumes of refined products, partially offset by higher prices for
crude oil and refined products. Operating expenses were higher in 1996 due
primarily to higher environmental and employee costs partially offset by lower
insurance costs.
EXPLORATION AND PRODUCTION
The following table summarizes the Exploration and Production segment's
results of operations for the years ended December 31, 1995, 1996 and 1997 and
the three months ended March 31, 1997 and 1998.
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
---------------------------- ------------------
1995 1996 1997 1997 1998
-------- ------- ------- ------- --------
(DOLLARS IN MILLIONS EXCEPT PER UNIT AMOUNTS)
<S> <C> <C> <C> <C> <C>
U.S.(a)(b)
Gross operating revenues........................ $ 113.0 $ 93.8 $ 73.6 $ 21.5 $ 19.1
Income from settlement of a natural gas
contract..................................... -- 60.0 -- -- --
Other income, including gain on asset sale in
1995......................................... 33.5 4.8 3.2 1.6 0.6
Production costs................................ 12.0 5.3 7.4 1.7 2.5
Administrative support and other operating
expenses..................................... 3.2 3.8 2.3 0.5 0.4
Depreciation, depletion and amortization........ 29.3 25.6 29.8 7.9 8.9
-------- ------- ------- ------- --------
Total Operating Profit -- U.S........... 102.0 123.9 37.3 13.0 7.9
-------- ------- ------- ------- --------
BOLIVIA
Gross operating revenues........................ 11.7 13.7 11.2 1.9 3.1
Other income related to collection of a
receivable................................... -- -- 2.2 -- --
Production costs................................ 0.6 0.8 0.9 0.2 0.3
Administrative support and other operating
expenses..................................... 3.2 2.8 2.4 0.5 0.6
Depreciation, depletion and amortization........ 0.3 1.3 1.5 0.2 0.5
-------- ------- ------- ------- --------
Total Operating Profit -- Bolivia....... 7.6 8.8 8.6 1.0 1.7
-------- ------- ------- ------- --------
TOTAL OPERATING PROFIT -- EXPLORATION AND
PRODUCTION...................................... $ 109.6 $ 132.7 $ 45.9 $ 14.0 $ 9.6
======== ======= ======= ======= ========
U.S.
Average Daily Net Production:
Natural gas (Mcf)............................ 114,490 87,654 86,052 94,103 99,135
Oil (barrels)................................ 1 27 118 145 173
Total (Mcfe)................................. 114,496 87,816 86,760 94,973 100,173
Average Prices:
Natural gas ($/Mcf) --
Spot market(c)............................. $ 1.34 $ 1.95 $ 2.17 $ 2.34 $ 2.01
Average(b)................................. $ 2.57 $ 2.75 $ 2.17 $ 2.34 $ 2.01
Oil ($/barrel)............................... $ 16.82 $ 21.99 $ 18.90 $ 21.14 $ 14.13
Average Operating Expenses ($/Mcfe):
Lease operating expenses..................... $ 0.11 $ 0.14 $ 0.20 $ 0.16 $ 0.21
Severance taxes.............................. 0.18 0.03 0.03 0.04 0.06
-------- ------- ------- ------- --------
Total production costs.................. 0.29 0.17 0.23 0.20 0.27
Administrative support and other............. 0.06 0.10 0.07 0.05 0.05
-------- ------- ------- ------- --------
Total Operating Expenses................ $ 0.35 $ 0.27 $ 0.30 $ 0.25 $ 0.32
======== ======= ======= ======= ========
Depletion ($/Mcfe).............................. $ 0.69 $ 0.79 $ 0.93 $ 0.91 $ 0.97
Capital Expenditures (including U.S. gas
transportation).............................. $ 49.6 $ 59.7 $ 65.4 $ 7.0 $ 18.2
</TABLE>
54
<PAGE> 58
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
---------------------------- ------------------
1995 1996 1997 1997 1998
-------- ------- ------- ------- --------
(DOLLARS IN MILLIONS EXCEPT PER UNIT AMOUNTS)
<S> <C> <C> <C> <C> <C>
BOLIVIA
Average Daily Net Production:
Natural gas (Mcf)............................ 18,650 20,251 19,537 10,999 22,769
Condensate (barrels)......................... 567 584 518 316 816
Total (Mcfe)................................. 22,052 23,755 22,645 12,895 27,665
Average Prices:
Natural gas ($/Mcf).......................... $ 1.28 $ 1.33 $ 1.15 $ 1.32 $ 0.97
Condensate ($/barrel)........................ $ 14.39 $ 17.98 $ 15.71 $ 19.28 $ 15.78
Average Operating Expenses ($/Mcfe):
Production costs............................. $ 0.07 $ 0.10 $ 0.11 $ 0.16 $ 0.11
Value-added taxes............................ 0.06 0.05 -- -- --
Administrative support and other............. 0.35 0.27 0.31 0.41 0.29
-------- ------- ------- ------- --------
Total Operating Expenses................ $ 0.48 $ 0.42 $ 0.42 $ 0.57 $ 0.40
======== ======= ======= ======= ========
Depletion ($/Mcfe).............................. $ 0.03 $ 0.15 $ 0.19 $ 0.15 $ 0.21
Capital Expenditures............................ $ 3.8 $ 6.9 $ 27.5 $ 4.0 $ 2.3
</TABLE>
- ---------------
(a) Represents Tesoro's U.S. oil and gas operations combined with gas
transportation activities.
(b) Results for the years 1995 and 1996 included revenues from above-market
pricing provisions of a contract with Tennessee Gas which was terminated
effective October 1, 1996. Operating profit for the years 1995 and 1996
included $47.1 million and $24.6 million, respectively, for the excess of
these contract prices over spot market prices. Net natural gas production
sold under the contract averaged approximately 20 million cubic feet
("MMcf") per day in 1995 and 11 MMcf per day in 1996. Upon termination of
the contract, Tesoro recorded other income and operating profit of $60
million during the fourth quarter of 1996. See Note D of Notes to Tesoro's
Consolidated Financial Statements.
(c) Includes effects of Tesoro's natural gas commodity price agreements which
amounted to a gain of $0.01 per Mcf in the year 1995 and losses of $0.11
per Mcf and $0.05 per Mcf in the years 1996 and 1997 respectively, and a
loss of $0.19 per Mcf for the 1997 Quarter. There were no such agreements
during the 1998 Quarter.
EXPLORATION AND PRODUCTION -- U.S.
Three Months Ended March 31, 1998 Compared to Three Months Ended March 31,
1997
Operating profit from the Company's U.S. exploration and production
operations was $7.9 million in the 1998 Quarter compared with $13 million in the
1997 Quarter. While the Company's production increased by 5%, natural gas prices
declined by $0.33 per Mcf, or 14%, to $2.01 per Mcf in the 1998 Quarter compared
to $2.34 per Mcf in the 1997 Quarter. The 1997 Quarter also benefitted from
income of $1.6 million for retroactive severance tax refunds for production in
prior years, with no substantial refunds received in the 1998 Quarter.
The Company's production volumes averaged 100.2 MMcfe per day in the 1998
Quarter compared to 95.0 MMcfe per day in the quarter ended March 31, 1997. This
increase in the Company's production consisted of a 30.4 MMcf per day decline
from the Bob West Field offset by a 35.6 MMcfe per day production increase from
other U.S. fields. The Company's production outside of the Bob West Field rose
to 51% of total production during the 1998 Quarter, as compared to 17% in the
1997 Quarter.
Gross operating revenues from the Company's U.S. operations decreased by
$2.4 million, primarily due to lower spot market prices for sales of natural
gas. Other income was lower in the 1998 Quarter due to fewer refunds of
severance taxes. Production costs were higher by $0.8 million ($0.07 per Mcfe)
primarily due to higher lease operating expenses. Lease operating costs in the
aggregate for the Bob West Field remained relatively flat, while production
volumes have declined, resulting in an increase in per unit lease operating
expenses from $0.13 per Mcf in the 1997 Quarter to $0.22 per Mcf in the 1998
Quarter. Lease operating costs in the aggregate for other fields have doubled,
while production volumes have tripled, resulting in a decrease in
55
<PAGE> 59
per unit lease operating cost from $0.29 per Mcfe to $0.19 per Mcfe.
Depreciation, depletion and amortization increased by $1.0 million, or 13%, due
to a higher depletion rate and increased volumes.
From time to time, the Company enters into commodity price agreements to
reduce the risk caused by fluctuation in the prices of natural gas in the spot
market. During the 1997 Quarter, the Company used such agreements to set the
price of 34% of the natural gas production that it sold in the spot market and
recognized a loss of $1.6 million ($.19 per Mcf) related to these price
agreements. The Company did not have any such transactions during the 1998
Quarter.
Year Ended December 31, 1997 Compared to Year Ended December 31, 1996
Operating profit from Tesoro's U.S. exploration and production operations
was $37.3 million in 1997, compared with $123.9 million in 1996. Comparability
between these years was impacted by several major transactions in 1996,
including the favorable resolution in August 1996 of litigation regarding the
Tennessee Gas contract and the termination of the remainder of the contract
effective October 1, 1996. As provided for in the Tennessee Gas contract, which
was to expire in January 1999, Tesoro was selling a portion of the gas produced
in the Bob West Field pursuant to a contract price, which was substantially
above the average spot market price. In total, during 1996, Tesoro received
approximately $120 million in cash for the resolution of litigation and
termination of the Tennessee Gas contract, with Tesoro's Exploration and
Production segment recording operating profit of $60 million upon termination of
the contract. In 1996 and 1995, the Exploration and Production segment's
operating profit also included $24.6 million and $47.1 million, respectively,
from the excess of Tennessee Gas contract prices over spot market prices. See
Note D of Notes to Tesoro's Consolidated Financial Statements.
Additionally, during 1996, substantially all of Tesoro's proved producing
reserves in the Bob West Field were certified by the Texas Railroad Commission
as high-cost gas from a designated tight formation, eligible for state severance
tax exemptions from the date of first production through August 2001.
Accordingly, no severance tax is recorded on current production from the exempt
wells in the Bob West Field beginning in 1996. In 1997 and 1996, Tesoro
recognized income of $1.8 million and $5.0 million, respectively, for
retroactive severance tax refunds for production in prior years.
Excluding the impact of the incremental contract value and income from the
severance tax refunds, operating profit from Tesoro's U.S. operations would have
been $35.5 million in 1997 compared to $34.3 million in 1996. The resulting
increase of $1.2 million was primarily attributable to higher spot market prices
for sales of natural gas, partially offset by higher depletion and operating
expenses.
Prices realized by Tesoro on its natural gas production sold in the spot
market increased 11% to $2.17 per Mcf in 1997 from $1.95 per Mcf in 1996.
Tesoro's weighted average sales price, which included the above-market pricing
of the Tennessee Gas contract in 1996, decreased in 1997 due to the termination
of the contract. Tesoro's net production averaged 86.8 MMcfe per day in 1997, a
decrease of 1.0 MMcfe per day from 1996. This decrease consisted of a 16.1 MMcf
per day decline from the Bob West Field, partially offset by a 15.1 MMcfe per
day increase from other U.S. fields. Tesoro's U.S. production outside of the Bob
West Field rose to 50% of its total U.S. production by January 1998, as compared
to 7% at 1996 year-end.
Gross operating revenues from Tesoro's U.S. operations, after excluding
amounts related to Tennessee Gas, increased due to the higher spot market
prices. Production costs were higher by $2.1 million ($0.06 per Mcfe) due mainly
to costs at the Bob West Field, including increased compression costs and a
charge for ad valorem taxes in 1997 as well as the impact of lower processing
fees in 1996. Administrative support and other operating expenses decreased by
$1.5 million. Depreciation and depletion increased by $4.2 million, or 16%, due
to a higher depletion rate.
From time to time, Tesoro enters into commodity price agreements to reduce
the risk caused by fluctuations in the prices of natural gas in the spot market.
During 1997, 1996 and 1995, Tesoro used such agreements to set the price of 9%,
30% and 38%, respectively, of the natural gas production that it sold in the
spot market. During 1997 and 1996, Tesoro realized losses of $1.6 million ($0.05
per Mcf) and $3.1 million ($0.11 per Mcf), respectively, from these price
agreements. In 1995, the effects of natural gas price
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<PAGE> 60
agreements resulted in a gain of $0.3 million ($0.01 per Mcf). Tesoro had no
remaining price agreements outstanding at December 31, 1997.
Year Ended December 31, 1996 Compared to Year Ended December 31, 1995
Operating profit of $123.9 million from Tesoro's U.S. exploration and
production operations in 1996 increased $21.9 million from operating profit of
$102.0 million in 1995. Comparability between these years was impacted by
several major transactions. As discussed above, the 1996 results included the
impact of the incremental value of the Tennessee Gas contract. Operating profit
for 1995 included a gain of $33.5 million from the sale of certain interests in
the Bob West Field (see Note C of Notes to Tesoro's Consolidated Financial
Statements). Excluding the impact of the incremental contract value from both
years and the gain on sale of assets from 1995, operating profit from Tesoro's
U.S. operations for 1996 would have been $34 million compared to $21 million for
1995. The resulting increase was primarily due to higher spot market prices for
sales of natural gas as industry demand increased due to unusually cold weather
combined with below-normal storage levels.
Prices realized by Tesoro on its natural gas production sold in the spot
market increased 46% to $1.95 per Mcf in 1996 from $1.34 per Mcf in 1995.
Excluding 24,500 Mcf per day related to the sold interests from 1995, Tesoro's
spot production increased by 6,600 Mcf per day during 1996. Tesoro's exploration
and acquisition programs outside of the Bob West Field contributed 3,800 Mcf per
day of the increase in spot production with the remaining increase attributable
to sales to Tennessee Gas at spot prices effective October 1, 1996. Tesoro's
weighted average sales price increased 7% to $2.75 per Mcf in 1996 as compared
to $2.57 per Mcf in 1995. The Bob West Field production declined by 6,100 Mcf
per day after excluding amounts related to sold interests in 1995.
Gross operating revenues from Tesoro's U.S. operations, after excluding
$11.7 million related to the sold interests from 1995, decreased by $7.5 million
due primarily to the decline in volumes sold under the Tennessee Gas contract,
and losses under commodity price agreements discussed above, partially offset by
increases in spot market sales prices and production. The decline in production
costs of $6.7 million, or $0.12 per Mcfe, was mainly attributable to the
severance tax exemptions in the Bob West Field. Total depreciation, depletion
and amortization was lower in 1996 due to lower production volumes, partially
offset by a higher depletion rate.
EXPLORATION AND PRODUCTION -- BOLIVIA
Tesoro's Bolivian natural gas production is sold to Yacimientos
Petroliferos Fiscales Bolivianos ("YPFB"), a Bolivian governmental agency, which
in turn sells the natural gas to Yacimientos Petroliferos Fiscales, SA ("YPF"),
a publicly-held company based in Argentina. Currently, Tesoro's sales of natural
gas production are based on the volume and pricing terms in a contract between
YPFB and YPF, which was extended in April 1997 for an additional two years to
March 31, 1999, with an option to extend the contract a maximum of one
additional year if a pipeline being constructed from Bolivia to Brazil is not
complete. In the contract extension, YPF negotiated an 11% reduction in the
minimum contract volume that it is required to import from Bolivia, which in
turn resulted in a corresponding 11% reduction of Tesoro's minimum contract
volume to 36.9 MMcf per day gross (26.2 net). The contract gas prices fluctuate
since they are linked to a monthly average fuel oil price posted in the New York
spot market.
A lack of market access has constrained natural gas production in Bolivia.
Tesoro believes that the completion of a 1,900-mile pipeline from Bolivia to
Brazil will provide access to larger gas-consuming markets. Upon completion of
this pipeline, Tesoro will face intense competition from major and independent
natural gas companies operating in Bolivia for a share of the contractual
volumes to be exported to Brazil. It is anticipated that each producer's share
of the contractual volumes will be allocated by YPFB according to a number of
factors, including each producer's reserve volumes and production capacity.
Although Tesoro expects gas deliveries on the pipeline to begin in early 1999,
there can be no assurance that the pipeline will be operational by such date.
With the exception of the volumes currently under contract with the Bolivian
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<PAGE> 61
government, Tesoro cannot be assured of the amount of additional volumes that
will be exported to Brazil upon completion of the pipeline.
Three Months Ended March 31, 1998 Compared to Three Months Ended March 31,
1997
Operating profit from the Company's Bolivian operations increased to $1.7
million in the 1998 Quarter, from $1.0 million operating profit in the 1997
Quarter. Although Bolivian natural gas prices fell to $0.97 per Mcf from $1.32
per Mcf realized in the 1997 Quarter, net production volumes more than doubled
to 27.7 Mmcfe per day from 12.9 Mmcfe per day in the 1997 Quarter. Production in
the 1997 Quarter was affected by lower contractual purchases made to balance
prior over-production in 1996 and also by constraints from repairs to a
non-Company-owned pipeline that transports gas from Bolivia to Argentina.
Additionally, production in the 1998 Quarter reflects an increase resulting from
the Company's purchase of interests held by its former joint venture participant
in July 1997.
Year Ended December 31, 1997 Compared to Year Ended December 31, 1996
Operating profit from Tesoro's Bolivian operations decreased to $8.6
million in 1997, from $8.8 million operating profit in 1996. Results for 1997
benefitted from income of $2.2 million related to the collection of a receivable
for prior years' production. Without this income, operating profit would have
decreased by $2.4 million in 1997 due to declines in natural gas and condensate
production and prices. With Tesoro's purchase of interests held by its former
joint venture participant in July 1997, Tesoro's share of production from
Bolivia increased by approximately 33% beginning in the 1997 third quarter (see
Note C of Notes to Tesoro's Consolidated Financial Statements). However, earlier
in the year, Tesoro's Bolivian natural gas production was lower due to a
reduction in minimum takes under the new contract between YPFB and YPF and also
due to constraints arising from repairs to a third-party pipeline that
transports gas from Bolivia to Argentina. In addition, during 1996, production
was higher due to requests from YPFB for additional production from Tesoro to
meet export specifications. Natural gas prices fell 14% to $1.15 per Mcf in
1997, compared to $1.33 per Mcf in 1996. Condensate prices fell 13% to $15.71
per barrel in 1997, compared to $17.98 per barrel in 1996.
Year Ended December 31, 1996 Compared to Year Ended December 31, 1995
Operating profit from Tesoro's Bolivian operations increased to $8.8
million in 1996, from the $7.6 million operating profit in 1995. This
improvement was primarily due to a 9% increase in production of natural gas,
primarily due to increased demand from YPFB during the second and third quarters
of 1996, together with higher prices received for both natural gas and
condensate. Operating expenses declined by 12% on a per unit basis reflecting a
6% decrease in costs combined with the increase in volumes. Partially offsetting
these improvements was an increase in depreciation, depletion and amortization
of $1.0 million.
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MARINE SERVICES
The following table summarizes the Marine Services segment's results of
operations for the years ended December 31, 1995, 1996 and 1997 and the three
months ended March 31, 1997 and 1998.
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
------------------------- ---------------
1995 1996 1997 1997 1998
------ ------ ------- ------ ------
(DOLLARS IN MILLIONS)
<S> <C> <C> <C> <C> <C>
Gross Operating Revenues
Fuels............................................... $61.9 $98.9 $104.5 $28.2 $25.8
Lubricants and other................................ 12.0 14.9 16.4 4.3 4.1
Services............................................ 0.6 8.7 11.3 3.0 2.9
----- ----- ------ ----- -----
Gross Operating Revenues.................... 74.5 122.5 132.2 35.5 32.8
Costs of Sales........................................ 64.9 93.0 96.7 27.3 23.6
----- ----- ------ ----- -----
Gross Profit................................ 9.6 29.5 35.5 8.2 9.2
Operating Expenses and Other.......................... 13.7 22.2 27.5 6.9 6.8
Depreciation and Amortization......................... 0.3 1.2 1.7 0.4 0.6
----- ----- ------ ----- -----
Operating Profit (Loss)..................... $(4.4) $ 6.1 $ 6.3 $ 0.9 $ 1.8
===== ===== ====== ===== =====
Capital Expenditures.................................. $ 0.4 $ 6.9 $ 9.4 $ 2.2 $ 1.2
</TABLE>
Three Months Ended March 31, 1998 Compared to Three Months Ended March 31,
1997
Gross operating revenues declined by $2.7 million during the 1998 Quarter
due primarily to lower fuel sales prices partly offset by increased volumes.
Cost of sales decreased by $3.7 million, which also reflects the lower fuel
prices. In total, operating profit improved by $0.9 million largely due to
increased margins.
The Marine Services business is largely dependent upon the volume of oil
and gas drilling, workover, construction and seismic activity in the Gulf of
Mexico.
Year Ended December 31, 1997 Compared to Year Ended December 31, 1996
Gross operating revenues increased by $9.7 million, which included a $7.1
million increase in fuels and lubricant revenues and a $2.6 million increase in
service revenues. The increase in fuels and lubricant revenues was primarily due
to a 10% increase in sales volumes, partially offset by lower prices. The
service revenue increase of 30% was due in part to increased rig activity in the
Gulf of Mexico and Tesoro's focus to serve these customers. Additional terminal
locations stemming from an acquisition consummated in February 1996 together
with internal growth initiatives have enabled Tesoro to increase its sales
activity. Costs of sales increased in 1997 due to the higher volumes. The
improvement of $6.0 million in gross profit was offset by higher operating and
other expenses associated with the increased activity together with upgrades to
facilities and services.
Year Ended December 31, 1996 Compared to Year Ended December 31, 1995
In February 1996, Tesoro acquired Coastwide Energy Services, Inc.
("Coastwide") and combined these operations with Tesoro's marine petroleum
products distribution business, forming a Marine Services segment. Operating
results from Coastwide have been included in Tesoro's Marine Services segment
since the date of acquisition. See Note C of Notes to Tesoro's Consolidated
Financial Statements.
The Marine Services segment consisted of 20 terminals at year-end 1996,
compared to 14 at the prior year-end. The increase of $39.9 million in fuels and
lubricants revenues was primarily due to the added locations and associated
volumes combined with higher fuel prices. In addition, revenues from services
grew by $8.1 million. These increases in revenues together with improved margins
during 1996 were partially offset by higher operating and other expenses
associated with the increased activity. Depreciation and amortization increased
during 1996 due to capital additions during the year. In total, operating profit
of $6.1 million in 1996 reflected a turnaround from the losses incurred in the
prior year.
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GENERAL AND ADMINISTRATIVE EXPENSES
General and administrative expenses increased from $3.0 million for the
1997 Quarter to $3.4 million for the 1998 Quarter. General and administrative
expenses were $13.6 million in the year 1997, compared with $12.7 million in the
year 1996 and $16.4 million in the year 1995. The increase in the year 1997 was
primarily due to higher employee costs partially offset by lower professional
fees and insurance costs. When comparing the year 1996 to the year 1995, the
decrease was primarily due to lower employee and labor costs resulting from cost
reduction measures implemented by Tesoro in late 1995.
INTEREST EXPENSE AND INTEREST INCOME
Interest expense of $2.7 million for the 1998 Quarter increased from the
$1.6 million in the 1997 Quarter primarily due to higher borrowings under
Tesoro's credit facility to fund net working capital requirements, arising
primarily from higher crude oil levels at the Alaska Refinery and to fund
capital expenditures. Interest expense totaled $6.7 million in the year 1997,
compared with $15.4 million in the year 1996 and $20.9 million in the year 1995.
Tesoro's redemption of public debt of $74.1 million in November 1996 and $34.6
million in December 1995 contributed to these interest savings.
Interest income was $1.6 million in the year 1997, compared with $8.4
million in the year 1996 and $1.8 million in the year 1995. The fluctuation in
the year 1996 included interest of approximately $7 million received from
Tennessee Gas in conjunction with the collection of a receivable which resulted
from underpayment for natural gas sold in prior periods (see Note D of Notes to
Tesoro's Consolidated Financial Statements).
OTHER EXPENSE, NET
Other expense was $4.9 million in the year 1997, compared with $10 million
in the year 1996 and $8.5 million in the year 1995. In the year 1996, Tesoro
incurred costs of $2.3 million to resolve a shareholder consent solicitation,
together with a write-off of deferred financing costs and increased expenses
related to Tesoro's former operations. There were no material comparable costs
recorded in the year 1997. When comparing the year 1996 to the year 1995, the
increase in other expense was due to the costs recorded in the year 1996,
partially offset by lower employee termination and restructuring costs.
INCOME TAX PROVISION
The income tax provision for the 1998 Quarter was $4.8 million (44%
effective tax rate) compared with $3.5 million (36% effective tax rate) for the
1997 Quarter. The increase in effective tax rate primarily reflects an increase
in foreign taxes related to Tesoro's Bolivian revenues. The income tax provision
was $18.4 million in the year 1997, compared with $38.3 million in the year 1996
and $4.4 million in the year 1995. Effective income tax rates were 7%, 33% and
37% in the years 1995, 1996 and 1997, respectively (see Note H of Notes to
Tesoro's Consolidated Financial Statements). The decrease in the income tax
provision in the year 1997 was primarily attributable to lower earnings,
partially offset by a higher effective rate due to Bolivian taxes. When
comparing the year 1996 to the year 1995, the income tax provision increased due
to earnings subject to U.S. taxes exceeding available net operating loss and tax
credit carryforwards.
CAPITAL RESOURCES AND LIQUIDITY
OVERVIEW
The Company's primary sources of liquidity are its cash and cash
equivalents, internal cash generation and external financing. The Company
operates in an environment in which 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
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<PAGE> 64
economic conditions. The Company's future capital expenditures as well as
borrowings under its credit arrangements and other sources of capital will be
affected by these conditions.
CREDIT ARRANGEMENTS
Upon issuance of the Old Notes in the Notes Offering, entering into the
Senior Credit Facility and the application of the estimated net proceeds
therefrom, the Company's pro forma indebtedness as of March 31, 1998 would have
been approximately $483.5 million (including the Notes, but excluding an
additional $350.0 million available under the Senior Credit Facility). The
Company's primary capital requirements are expected to include capital
expenditures, working capital and debt service. The primary sources of capital
are expected to be cash flow from operations and borrowings under the Senior
Credit Facility, which incurs interest at variable rates. Based upon current and
anticipated future operations and anticipated future cost savings, the Company
believes that available capital resources will be adequate to meet anticipated
future capital requirements. There can be no assurance, however, that the
Company's business will generate sufficient cash flow that, together with other
sources of capital, will enable the Company to service its indebtedness,
preferred stock dividend payments or make anticipated capital expenditures. If
the Company is unable to generate sufficient cash flow from operations or to
borrow sufficient funds in the future to service its debt, it may be required to
sell assets, reduce capital expenditures, refinance all or a portion of its
existing indebtedness, or obtain additional financing. See "Risk
Factors -- Substantial Leverage and Debt Service."
The Senior Credit Facility, the Notes and PIES and other debt instruments
of the Company, impose various restrictions and covenants on the Company that
could potentially limit the Company's ability to respond to market conditions,
to provide for unanticipated capital investments, to raise additional debt or
equity capital or to take advantage of business opportunities. See "Description
of Other Indebtedness," "Description of the Notes" and "Description of Capital
Stock."
CAPITAL SPENDING
Capital spending in 1997 totaled $147 million which was funded from
available cash reserves, internally-generated cash flows from operations and
external financing. Capital expenditures for the Exploration and Production
segment were approximately $93 million, including $65 million for U.S.
operations and $28 million for Bolivia operations. In the U.S., capital
expenditures were principally for participation in the drilling of 11
development wells (nine completed), 12 exploratory wells (eight completed), the
purchase of 33 Bcfe of proved reserves and 82,000 net undeveloped lease acres
and seismic activity. In Bolivia, capital expenditures included the purchase of
contract interests from its former joint venture participant (see Note C of
Notes to Tesoro's Consolidated Financial Statements), exploratory drilling,
seismic activity and workovers. Capital projects for the Refining and Marketing
segment in 1997 totaled $44 million, primarily for costs related to the
hydrocracker expansion and the commencement of a long-term capital program to
improve marketing operations. In the Marine Services segment, capital spending
totaled $9 million during 1997, primarily for expansion and improvement of
operations along the Gulf of Mexico.
For 1998, the Company has a total capital budget of approximately $195
million, excluding amounts required to fund the Acquisitions and capital
expenditures of $15 to $20 million in 1998 related to the Hawaii and Washington
operations following the Acquisitions. Through the quarter ended March 31, 1998,
the Company's capital spending totaled $24 million. The Exploration and
Production segment accounts for $139 million, or 71%, of the budget with $82
million planned for U.S. activities and $57 million for Bolivia. Planned U.S.
expenditures include $25 million for acquisitions, $21 million for development
drilling (participation in 30 gross wells), $17 million for leasehold,
geological and geophysical, and $17 million for exploratory drilling
(participation in 20 gross wells). In Bolivia, the drilling program is budgeted
at $14 million for development drilling (three wells) and $12 million for
exploratory drilling (two gross wells), with the remainder planned for upgrading
a gas processing plant, laying gathering lines to shut-in wells, workovers and
three-dimensional seismic activity. Capital spending, other than capital
expenditures related to the Hawaii and Washington operations, for the Refining
and Marketing segment is planned at approximately $39 million, which includes
$20 million towards the retail marketing expansion program in Alaska started in
1997, $8 million for environmental and $8 million for improvements to the Alaska
Refinery. The Marine Services
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<PAGE> 65
capital budget is $9 million, primarily directed towards equipment and facility
upgrades together with potential acquisitions. The Company also expects to spend
$7 million for corporate capital projects, including upgrades to information
systems. Capital expenditures for 1998 are expected to be financed through a
combination of cash flows from operations, available cash reserves and
additional borrowings under the Senior Credit Facility. Actual capital
expenditures may vary from these projections due to a number of factors,
including the timing of drilling projects and the extent to which properties are
acquired.
CASH FLOW SUMMARY
Components of Tesoro's cash flows are set forth below (in millions):
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
------------------------- ---------------
1995 1996 1997 1997 1998
------ ------ ------- ------ ------
<S> <C> <C> <C> <C> <C>
Cash Flows From (Used In):
Operating Activities................... $ 35.4 $178.9 $ 95.6 $ 23.8 $ 6.4
Investing Activities................... 2.4 (94.2) (151.5) (16.8) (29.5)
Financing Activities................... (37.8) (75.9) 41.5 1.6 17.0
------ ------ ------- ------ ------
Increase (Decrease) in Cash and Cash
Equivalents............................ $ -- $ 8.8 $ (14.4) $ 8.6 $ (6.1)
====== ====== ======= ====== ======
</TABLE>
Net cash from operating activities during the 1998 Quarter totaled $6
million, compared to $24 million in the 1997 Quarter. Although the level of
earnings during both quarters was relatively the same, working capital
components were higher during the 1998 Quarter. Net cash used in investing
activities of $29 million during the 1998 Quarter included capital expenditures
of $24 million, primarily in the Company's exploration and production segment,
and an escrow deposit of $5 million for the Hawaii Acquisition. Net cash from
financing activities of $17 million during the 1998 Quarter included additional
borrowings of $23 million under the Company's credit facility, partially offset
by payments of other long-term debt, including repayment and termination of a
marine services loan. During the 1998 Quarter, gross borrowings under revolving
credit lines were $110 million, with $92 million of repayments. At March 31,
1998, the Company's outstanding borrowings under its current credit facility
were $51 million and net working capital totaled $87 million, which included
cash and cash equivalents of $2.3 million.
During the year 1997, net cash from operating activities totaled $96
million, compared with $179 million in 1996. Operating cash flows in 1997
included a $57 million decrease in receivables due in part to collections
related to product and crude oil sales volumes at 1996 year-end, Bolivian
production sold in prior years and retroactive severance taxes, partially offset
by income tax and other payments. The 1996 operating cash flows included the
impact of receipts from Tennessee Gas. Net cash used in investing activities of
$151 million in 1997 included capital expenditures of $93 million for Tesoro's
Exploration and Production activities, $44 million for Refining and Marketing
activities and $9 million for Marine Services. Net cash from financing
activities of $41 million in 1997 included net borrowings of $28 million under
the former credit facility and receipt of $16 million under a loan for the
hydrocracker expansion, partially offset by payments of other long-term debt and
repurchases of Common Stock. During 1997, gross borrowings under Tesoro's former
credit facility were $150 million, with $122 million of repayments. At December
31, 1997, Tesoro's net working capital totaled $74 million, which included cash
and cash equivalents of $8 million.
During the year 1996, net cash from operating activities totaled $179
million, compared with $35 million in 1995. This increase in operating cash
flows in 1996 was primarily due to the receipt of $120 million from Tennessee
Gas for the favorable resolution of litigation in August 1996 and termination of
the natural gas purchase and sales contract effective October 1, 1996. In
addition, improved profitability plus noncash items, such as depreciation,
depletion and amortization and deferred income taxes, contributed to higher cash
flows from operations. Partially offsetting these increases were higher net
working capital balances, particularly receivables which increased primarily due
to higher year-end sales volumes together with higher prices. Net cash used in
investing activities of $94 million in 1996 included capital expenditures of $85
million and cash consideration of nearly $8 million for the acquisition of
Coastwide. Net cash used in financing activities of
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<PAGE> 66
$76 million during 1996 was primarily due to the redemption of public debt
aggregating $74 million together with payments of other long-term debt. During
1996, Tesoro's gross borrowings and repayments under its corporate revolving
credit line amounted to $165 million.
During the year 1995, net cash from operating activities totaled $35
million. Although natural gas production from Tesoro's South Texas operations
increased during 1995, lower cash receipts for sales of natural gas adversely
affected Tesoro's cash flows from operations. Net cash from investing activities
of $2 million in 1995 included proceeds of $70 million from sales of assets,
primarily certain interests in the Bob West Field, partially offset by $64
million of capital expenditures and $3 million for acquisition of the Kenai Pipe
Line Company ("KPL"). Net cash used in financing activities of $38 million in
1995 was primarily related to the redemption of $34.6 million of public debt and
payments of other long-term debt. Tesoro's gross borrowings and repayments under
the former credit facility totaled $262 million during 1995.
OTHER
On May 12, 1998, employee incentive payments were triggered when the high
and low trading price of the Company's Common Stock averaged $20 per share over
a 20 consecutive trading day period under an incentive strategy approved by the
Company's Board of Directors in June 1996. The triggering of those awards
reflects an aggregate increase of more than $250 million in the market value of
the Company's Common Stock since June 1996. The triggering of the incentive
program will result in a pretax charge of approximately $20 million (of which
approximately $10 million is non-cash) during the second quarter of 1998. On an
aftertax basis, the charge will be approximately $13 million which represents
approximately 5% of the increase in Tesoro's market value since June 1996. For
further information related to the incentive strategy, see Note K of Tesoro's
Notes to Condensed Consolidated Financial Statements.
The second quarter of 1998 will also reflect receipt of approximately $21
million pretax ($14 million aftertax) from an operator in the Bob West Field,
representing funds that are no longer needed as a contingency reserve for
litigation. These proceeds were used to reduce debt levels.
ENVIRONMENTAL
In connection with the Hawaii Acquisition, the Company and certain
subsidiaries of BHP (the "BHP Sellers") have executed an environmental agreement
in which the BHP Sellers have agreed to indemnify the Company for environmental
costs arising out of conditions at the Hawaii Refinery, terminals and retail
stations previously operated by BHP Hawaii which existed at or prior to May 31,
1998, the effective closing date of the Hawaii Acquisition, subject to a maximum
limit of $9.5 million. Under the environmental agreement, the first $5 million
of environmental costs are the responsibility of the BHP Sellers and the next $6
million are to be shared on the basis of 75% by the BHP Sellers and 25% by the
Company. The BHP Sellers' environmental indemnification will survive for a
ten-year period. Certain environmental claims arising out of prior operations of
the BHP Sellers are not subject to the $9.5 million limit or ten-year time limit
for claims made.
Under the agreement related to the Washington Acquisition, Shell Refining
Holding Company, a subsidiary of Shell, generally has agreed to indemnify the
Company for environmental liabilities at the Washington Refinery arising out of
conditions which existed at or prior to the closing date. However, the Company
is responsible for the first $0.5 million in environmental costs in each year
and 50% of environmental costs over $1 million in each year, subject to a
maximum aggregate liability of $5 million.
To comply with environmental laws and regulations, the Company anticipates
that it will make capital improvements of approximately $7 million in 1998 and
$2 million in 1999. In addition, capital expenditures for alternate secondary
containment systems for existing storage tank facilities are estimated to be $2
million in 1998 and $2 million in 1999 with a remaining $5 million to be spent
by 2002. At the Hawaii Refinery, the Company expects to make capital
improvements, including improvements to sulphur emission controls and new tank
roof seals, of $4 million in 1998 and $1 million in 1999. At the Washington
Refinery, the Company anticipates that it will make capital improvements of
approximately $2 million in 1998 and $1 million in 1999,
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<PAGE> 67
primarily for replacing certain storage tank seals and increasing the hydraulic
capacity of the facility storm water conveyance system.
The Company is subject to extensive foreign, 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 remediation response and
has incurred cleanup expenditures associated with environmental matters at a
number of sites, including certain of its current and prior-owned properties. At
March 31, 1998, Tesoro's accruals for environmental expenses amounted to $8.7
million, which included a noncurrent liability of $2.5 million for remediation
of KPL's properties that has been funded by the former owners of KPL through a
restricted escrow deposit.
Conditions that require additional expenditures may exist for various
Company sites, including, but not limited to, the Alaska Refinery, the Hawaii
Refinery, the Washington Refinery, retail stations (current and closed
locations) and petroleum product terminals, and for compliance with the Clean
Air Act, and other mandated programs. The amount of such future expenditures
cannot currently be determined by the Company. For further information on
environmental contingencies, see Note L of Notes to Tesoro's Consolidated
Financial Statements.
YEAR 2000 COMPLIANCE
The efficient operation of Tesoro'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 Tesoro's
business operating systems and controls, including information management
services and financial reporting, as well as in various administrative
functions. Tesoro has been evaluating its Systems and Programs to identify
potential year 2000 compliance problems, as well as manual processes, external
interfaces with customers and services supplied by vendors. The year 2000
problem refers to the limitations of the programming code in certain existing
hardware and software programs to recognize date sensitive information for the
year 2000 and beyond. Unless replaced or modified prior to the year 2000, such
hardware and systems may not properly recognize such information and could
generate erroneous data or cause a system to fail to operate properly.
Based on current information, Tesoro expects to attain year 2000 compliance
and institute appropriate testing of its modifications and replacements in a
timely fashion and in advance of the year 2000 date change. It is anticipated
that modification or replacement of Tesoro's Systems and Programs will be
performed in-house by company personnel. Tesoro 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 Tesoro. It is possible that non-compliant third party computer
systems or programs may not interface properly with Tesoro's computer systems.
Tesoro has requested assurance from third parties that their computers, systems
or programs be year 2000 compliant. Tesoro could, however, be adversely affected
by the year 2000 problem if it or unrelated parties fail to successfully address
this issue. Management of Tesoro currently anticipates that the expenses and
capital expenditures associated with its year 2000 compliance project will not
have a material effect on its financial position or results of operations.
Tesoro has recently undertaken a review of the year 2000 compliance status
of BHP Hawaii and Shell Washington, and is currently unable to determine whether
it has exposure to contingencies related to the year 2000 issue in connection
with the Acquisitions.
NEW ACCOUNTING STANDARDS
In June 1997, the FASB issued SFAS No. 131, "Disclosures about Segments of
an Enterprise and Related Information," which establishes standards for
reporting information about operating segments in annual financial statements
and requires that selected information about operating segments be included in
interim financial reports issued to shareholders. SFAS No. 131 also establishes
standards for related disclosures about products and services, geographic areas
and major customers. SFAS No. 131 becomes
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effective for the Company's 1998 year-end and need not be applied to interim
financial information until 1999. In February 1998, the FASB issued SFAS No.
132, "Employers' Disclosures about Pensions and Other Postretirement Benefits,"
which standardizes the disclosures related to pensions and other postretirement
benefits to the extent practicable, requires additional information on changes
in the benefit obligations and fair values of plan assets and eliminates certain
disclosures previously required. SFAS No. 132 becomes effective for the Company
in 1998. Both statements contain provisions for restatement of prior period
information. The Company is evaluating the effects that these new statements
will have on its financial reporting and disclosures. The new statements will
have no effect on the Company's results of operations, financial position or
cash flows.
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BUSINESS
GENERAL
The Company is a diversified natural resource company engaged in petroleum
refining, distributing and marketing of petroleum products, marine logistics
services and the exploration and production of natural gas and oil. These
operations are conducted through three business segments: Refining and
Marketing, Exploration and Production, and Marine Services.
The Company is the second largest independent refiner and the fifth largest
refiner overall in PADD V. The Company's Refining and Marketing segment operates
petroleum refineries at Kenai, Alaska; Kapolei, Hawaii; and Anacortes,
Washington. The Company currently sells gasoline through a large network of
branded stations in Alaska and Hawaii and is expanding its retail gasoline
marketing presence in the Pacific Northwest. This segment is also a major
supplier of jet fuel to the Anchorage, Honolulu and the Seattle/Tacoma airports
and diesel fuel to Alaska, Hawaii and Washington's fishing and marine
industries. The Company's Marine Services segment operates through a network of
23 marine terminals located in Louisiana and Texas and on the U.S. West Coast,
distributing petroleum products and providing logistics services to the offshore
drilling industry and other customers. Upstream, the Company's Exploration and
Production segment focuses on exploration, development and production of natural
gas and oil onshore in Texas, Louisiana and Bolivia. The Company's net proved
worldwide reserves totaled 517 Bcfe of natural gas at year-end 1997.
The Company's strategy is to (i) maximize return on capital employed and
increase the competitiveness of each of its business units by reducing costs,
increasing operating efficiencies and optimizing existing assets and (ii) expand
its overall market presence through a combination of internal growth initiatives
and selective acquisitions which are both accretive to earnings and provide
significant operational synergies.
Tesoro was incorporated in Delaware in 1968 (a successor by merger to a
California corporation incorporated in 1939). Its principal executive offices
are located at 8700 Tesoro Drive, San Antonio, Texas 78217-6218 and its
telephone number is (800) 837-6768.
REFINING AND MARKETING
OVERVIEW
The Company conducts petroleum refining operations in Alaska, Washington
and Hawaii and sells refined products to a wide variety of customers in Alaska
and Hawaii, along the U.S. West Coast, primarily in the Pacific Northwest,
American Samoa, Tahiti and in certain Far Eastern markets, including Russia,
Japan and Korea.
REFINERIES
ALASKA
The Alaska Refinery has a rated throughput capacity of 72,000 bpd and is
capable of producing liquefied petroleum gas, gasoline, jet fuel, diesel fuel,
heating oil, liquid asphalt, heavy oils and residual products. Alaska North
Slope ("ANS") and Cook Inlet crude oils are the primary feedstocks for the
Alaska Refinery. To assure the availability of crude oil to the Alaska Refinery,
the Company has a royalty crude oil purchase contract with the State of Alaska
and contracts with various Cook Inlet producers (see "-- Crude Oil Supply"
discussed below). During 1997, these crude oils were processed to yield refined
products consisting of approximately 25% gasoline, 42% middle distillates, 29%
heavy oils and residual products and 4% other products. Throughput at the Alaska
Refinery was reduced during both 1997 and 1996 for scheduled 30-day maintenance
turnarounds.
In early October 1997, the Company completed an expansion of the Alaska
Refinery's hydrocracker unit, which increased the unit's capacity by
approximately 25% to 12,500 bpd and enables the Company to produce more jet
fuel, a product currently in short supply in Alaska. The expansion, together
with the addition of a
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new, high-yield jet fuel hydrocracker catalyst, cost approximately $19 million
and has a projected payback period of two years. The expansion, together with
increased shipments of Cook Inlet crude oil beginning in October 1997, began to
improve the Alaska Refinery's product slate during the fourth quarter of 1997.
HAWAII
The Hawaii Refinery, located 22 miles west of Honolulu, Hawaii, has a rated
throughput capacity of 95,000 bpd and is the largest refinery in the state. It
is capable of producing liquefied petroleum gas, gasoline, jet fuel, diesel
fuel, fuel oil for ships and electrical power plants and liquid asphalt.
ANS and crude oil from Australia and Southeast Asia are the primary
feedstocks for the Hawaii Refinery. During 1997, these crude oils were processed
to yield refined products consisting of approximately 45% middle distillates,
28% gasoline, naphtha and liquefied petroleum gases, and 27% residual fuel oil.
Crude throughput at the Hawaii Refinery was reduced by 20% in June and July of
1997 to allow a scheduled maintenance turnaround on the marine mooring facility.
Planned shutdowns were taken in January 1996 and March 1997 on the catalytic
reformer unit to allow regeneration of catalyst, and the Hawaii Refinery was
shut down for approximately 26 days beginning in late June 1998 for a routine
maintenance turnaround.
In addition to crude and vacuum distillation, refining operations include
catalytic reforming, hydrocracking, hydrogen generation, visbreaking, light ends
recovery and liquid asphalt production.
WASHINGTON
The Washington Refinery has a rated throughput capacity of 108,000 bpd and
is the third largest refinery in the Pacific Northwest. The Washington Refinery
is located approximately 60 miles north of Seattle near Anacortes, Washington.
Approximately 35% of the refinery's crude oil feedstock is ANS with the
remaining sources primarily from Canada. Crude oil feedstock is received via
ship across the Company's dock in the Puget Sound and via pipeline. During 1997,
the Washington Refinery yielded a product slate comprised of approximately 53%
gasoline, 24% middle distillates and 23% residual fuel oil and other heavy oil
products. Although Shell incorporated Shell Washington on January 4, 1996, Shell
Washington commenced operations on May 1, 1996.
CRUDE OIL SUPPLY
ALASKA
The Alaska Refinery is designed to process crude oil with up to 1.0%
sulphur content. As such, the Alaska Refinery can process Cook Inlet, ANS and
certain other foreign and domestic crude oils. Historically, the Company's
Alaska Refinery has processed primarily ANS crude oil. Beginning in the fourth
quarter of 1997, Cook Inlet crude became a major feedstock for the Alaska
Refinery and the Company anticipates that Cook Inlet will be a major feedstock
for 1998.
Cook Inlet Crude Oil. Cook Inlet crude oil, a lighter crude oil that
contains an average of 0.1% sulphur, accounted for 26% of the Alaska Refinery's
feedstock in 1997. In the first nine months of 1997, the Company processed
approximately 9,300 bpd of Cook Inlet crude oil, or 19% of the Alaska Refinery's
throughput, which was obtained from several producers on the Kenai peninsula
under short-term contracts. During October 1997, the Company began purchasing
all of the approximately 34,000 bpd of Cook Inlet production from various
producers under contracts that extend through December 1998. A contract to
purchase 4,500 bpd, of the 34,000 bpd, has been extended through March 31, 2001.
During the fourth quarter of 1997, the Company processed approximately 24,900
bpd of Cook Inlet crude oil, or approximately 44% of the Alaska Refinery's
throughput. During 1998, the Company expects that Cook Inlet crude oil will be a
major feedstock for the Alaska Refinery.
Cook Inlet crude oil is delivered by tanker through KPL's marine terminal
or by pipeline to the Alaska Refinery.
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ANS Crude Oil. ANS crude oil, a heavy crude oil which has a sulphur content
of approximately 1.0%, accounted for 71% of the Alaska Refinery's feedstock in
1997. The Company purchased approximately 35,700 bpd of ANS crude oil during
1997 under the royalty crude oil purchase contract with the state of Alaska.
This contract, which covers the period January 1, 1996, through December 31,
1998, provides for the purchase of 30% of the state of Alaska ANS royalty crude
oil produced from the Prudhoe Bay Unit at prices based on royalty values
computed by the state of Alaska. The contract contains provisions that, under
certain conditions, allow the Company to temporarily or permanently reduce its
purchase obligation. Under the contract, the Company is required to utilize in
its Alaska Refinery operations volumes equal to at least 80% of the ANS crude
oil purchased from the state of Alaska. The Company is presently in discussions
with the state of Alaska in regard to extending this contract for an additional
year.
Tesoro also purchases approximately 6,000 bpd of ANS crude oil from a
producer under a contract with a term of one year which began January 1, 1998.
ANS crude oil feedstock is delivered to the Alaska Refinery by a
Tesoro-chartered tanker through the KPL marine terminal, which is owned and
operated by the Company.
For information related to a settlement of a contractual dispute with the
state of Alaska, see Note I of Notes to Tesoro's Consolidated Financial
Statements.
Other Supply. In 1997, the Alaska Refinery obtained 3% of its feedstock
supply from other sources. The other supply primarily consisted of spot
purchases of crude oil which were delivered to the Alaska Refinery by tanker
through KPL's marine terminal. The Company evaluates the economic viability of
processing various types of foreign and domestic crude oils in the Alaska
Refinery and will occasionally purchase spot quantities to supplement its normal
crude oil supply.
HAWAII
The Hawaii Refinery has the ability to process a wide range of crudes and
is located geographically such that it is economic to transport and receive
crudes from several parts of the world. The Hawaii Refinery is designed to
process crude with a sulphur content as high as 1.0% and also has the capability
to process combinations of crudes with naphtha/gasoline content as high as 35%
and residual fuel oil content as high as 30%. The Hawaii Refinery has processed
crude oil from Alaska, Australia, Malaysia, Indonesia and occasionally from
other countries. The Company evaluates the economics of a wide range of crudes
on a regular basis and is able to respond to movements in regional trading
markets by changing crude selection. The Company currently purchases 10,000 bpd
of Indonesian Duri crude oil from two suppliers under three one-year contracts
and 20,000 bpd of ANS crude oil from a producer under a 90-day contract with an
evergreen clause. All other crude oil is purchased on a spot basis. In
connection with the Hawaii Acquisition, the Company and an affiliate of BHP
entered into a crude supply agreement pursuant to which the BHP affiliate will
assist the Company in acquiring crude oil feedstock sourced outside of North
America and arrange for transportation of such crude oil to the Hawaii Refinery.
The crude supply agreement is for a period of two years and provides for annual
payments of $1.4 million by the Company to the BHP affiliate for such services.
WASHINGTON
Waterborne cargos, primarily ANS, are received over the refinery ship dock
and Canadian crude is received via Transmountain Pipeline. Either facility has
the capability to provide almost 100% of the Washington Refinery's needs.
Historically, approximately 60% of the Washington Refinery's crude supply has
been sweet Canadian crude received from the pipeline. However, after the
expansion of the sulphur plant anticipated to be completed in September 1998,
the Washington Refinery will be able to receive and process heavy Canadian crude
which has a higher sulphur content. Butanes are received through the Washington
Refinery's rail car rack. Small volumes of miscellaneous feedstocks are received
by barge. Both the ANS and Canadian crudes are purchased from a variety of
producers under multiple contracts.
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MARKETING
ALASKA
Gasoline. The Company distributes gasoline to end users in Alaska, either
by retail sales through 35 Company-operated stations, by wholesale sales through
125 branded and 25 unbranded dealers and jobbers (as of March 31, 1998) or by
deliveries to major oil companies for their retail operations in Alaska in
exchange for gasoline delivered to the Company on the U.S. West Coast. During
1997, the Company-operated retail stations sold an aggregate of 93,000 gallons
of gasoline per day.
In 1997, the Company initiated a three-year, $50 million retail marketing
expansion program focused primarily in Anchorage, Alaska, the state's largest
motor fuel market. During the year, two new retail stations were built, three
stations were remodeled and two uneconomic stations were closed. In addition, in
late 1997, the Company purchased the Union 76 marketing assets in Alaska, which
included three retail stations located in Southeast Alaska and the rights to use
the Union 76 trademark within Alaska.
Gasoline produced in excess of Alaska's market demand is shipped to the
U.S. West Coast or exported to the Far East by chartered vessel.
Middle Distillates. The Company is a major supplier of commercial jet fuel
into the Alaskan marketplace, with a majority of its production being marketed
to passenger and cargo airlines. The demand for jet fuel in Alaska is growing
and currently exceeds the production of all refiners in Alaska. Several
marketers, including the Company, import jet fuel into Alaska to meet excess
demand. The expansion of the Alaska Refinery's hydrocracker unit has increased
the Company's jet fuel production to help meet this growing market.
Substantially all of the Company's diesel fuel production is sold on a
wholesale basis in Alaska primarily for marine, transportation and industrial
purposes. As part of the purchase of the Union 76 marketing assets discussed
above, the Company acquired a terminal with a 110,000-barrel capacity in
Ketchikan, Alaska. Diesel fuel will be supplied to this terminal from the Alaska
Refinery and the U.S. West Coast. The product will be delivered to the terminal
by marine barge. Generally, the production of diesel fuel by refiners in Alaska
is in balance with demand; however, because of the variability of the demand,
there are occasions when diesel fuel is imported into or exported from Alaska.
See "-- Government Regulation and Legislation -- Environmental Controls" for a
discussion of the effect of governmental regulations on the production of
low-sulphur diesel fuel for on-highway use in Alaska.
Heavy Oils and Residual Products. The Alaska Refinery's vacuum unit uses
crude tower bottoms as a feedstock and further processes these volumes into
light vacuum gas oil ("LVGO"), heavy vacuum gas oil ("HVGO") and vacuum tower
bottoms ("VTBs"). The LVGO is further processed in the Alaska Refinery's
hydrocracker where it is converted into gasoline and jet fuel. HVGO is sold to
refiners on the U.S. West Coast where it is used as fluid catalytic cracker
feedstock. The VTBs are used to produce liquid asphalt or they are sold on the
U.S. West Coast. The Company sells its liquid asphalt, which is used in the
manufacturing of highway paving materials, primarily in Alaska where the demand
is seasonal because mild weather conditions are needed for highway construction.
During 1997, the Company opened an asphalt marketing facility in Anchorage,
which helped increase sales of this product in Alaska.
HAWAII
Petroleum products manufactured at the Hawaii Refinery are sold under
various contracts on a term basis or on a spot basis principally in Hawaii, the
Far East, the Pacific Islands and, to a lesser extent, the U.S. West Coast.
Gasoline. The Company distributes gasoline to end users in Hawaii by retail
sales through 30 Company-operated stations and by wholesale sales through two
dealer-operated stations or by deliveries to major oil companies for their
retail operations in Hawaii. During 1997, the Company-operated retail stations
sold an average of 120,500 gallons of gasoline and diesel per day.
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In 1994, BHP Hawaii initiated a three-year, $26 million retail gas station
and convenience store upgrade program. Since 1994, three new retail facilities
were built, two were purchased, five stations were rebuilt and 18 stations and
three car washes were remodeled.
Middle Distillates. The Company is the major supplier of commercial jet
fuel into the Hawaiian marketplace with a majority of its production being
marketed to passenger airlines. The demand for jet fuel currently exceeds the
production of both refiners in Hawaii. Several marketers, including BHP Hawaii,
import jet fuel into Hawaii to meet demand.
Substantially all of the Company's diesel fuel production is sold on a
wholesale basis in Hawaii primarily for marine, transportation, utility and
military purposes. Generally, the production of diesel by refiners in Hawaii is
in balance with demand. However, because of the variability of demand, there are
occasions when diesel fuel is imported into or exported from Hawaii.
Heavy Oils and Residual Products. The Hawaii Refinery's vacuum unit uses
crude tower bottoms as feedstock and further processes these volumes into medium
vacuum gas oil ("MVGO"), HVGO and VTBs. The MVGO is further processed in the
Hawaii Refinery's hydrocracker where it is converted into naphtha, jet fuel and
diesel. The HVGO is primarily used within the Hawaii Refinery for fuel oil
blending and occasionally sold to other refiners for use as fluid catalytic
cracker feedstock when inventories and economics are favorable. The VTBs are
used to produce liquid asphalt or are visbroken and blended to produce bunker
fuel or low sulphur fuel for use by utility power producers in Hawaii.
PACIFIC NORTHWEST
The Washington Refinery produces a variety of products including gasoline,
CARB gasoline, diesel, jet fuel, residual fuel and liquefied petroleum gases. Up
to 35% of the gasoline production will be sold to Shell through an off-take
agreement, approximately 30% is sold in the spot market and Chevron receives
approximately 30% in exchange for products in California. Jet fuel is sold
primarily to the Seattle/Tacoma Airport via pipeline. Diesel is sold to barging
companies and via truck rack. Heavy oil and residual products are currently sold
to another refiner and, locally, as bunker fuel. Upon completion of an asphalt
facility, a portion of the bottoms will be marketed as liquid asphalt. Combined
with the Alaska Refinery's production of heavy oil, the Company will be the
largest marketer of bunker fuels in the Pacific Northwest.
The Company conducts wholesale marketing operations along the U.S. West
Coast, primarily in Oregon and Washington, selling refined products in the bulk
market and through eight terminal facilities, including three operated by the
Company. In 1997, these operations sold approximately 10,300 bpd of refined
products, primarily gasoline and diesel fuel, of which approximately 25% was
received from major oil companies in exchange for products from the Alaska
Refinery, approximately 24% was received directly from the Alaska Refinery and
51% was purchased from other suppliers. In January 1998, operations of the three
Company-operated facilities on the U.S. West Coast were transferred to the
Company's Marine Services segment.
The Company's retail presence in Oregon and Washington was expanded during
1997 by adding 12 branded stations, bringing the number of "Tesoro Alaska"
branded gasoline stations in the Pacific Northwest to 30 at year-end. The
Washington Acquisition will not include any retail outlets.
FAR EAST
From time to time, the Company exports refined products from the Alaska
Refinery to certain markets in the Far East, including Russia. These exported
products, primarily gasoline, are transported to the Far East by a chartered
Russian flag vessel, described below, or at times by spot charters. Gasoline
blendstocks (reformate and naphtha) produced in excess of Hawaii's market is
exported to the Far East.
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TRANSPORTATION
ALASKA
The Company charters two American flag vessels, the Potomac Trader and the
Chesapeake Trader. These vessels are used to transport ANS crude oil from the
Trans Alaska Pipeline System ("TAPS") terminal at Valdez, Alaska, and Cook Inlet
crude oil from the Drift River terminal to the Alaska Refinery. The vessels are
also used to transport heavy oils and residual products to the U.S. West Coast
and occasionally to transport other feedstocks or products to the Alaska
Refinery. The Potomac Trader and the Chesapeake Trader are chartered under
five-year agreements expiring in 2000. The Company charters a Russian flag
vessel, the Igrim, to primarily transport refined products from the Alaska
Refinery to the Far East. The Igrim is chartered under an agreement expiring in
June 1999, which may be extended at the Company's option through June 2000. The
Company plans to continue marketing its products in the Far East and is
evaluating transportation alternatives. From time to time, the Company also
charters tankers and ocean-going barges to transport petroleum products to its
customers within Alaska, on the U.S. West Coast and in the Far East.
The Company operates a common carrier petroleum products pipeline from the
Alaska Refinery to its terminal in Anchorage. This ten-inch diameter pipeline
has a capacity to transport approximately 40,000 barrels of petroleum products
per day and allows the Company to transport light products to the terminal
throughout the year regardless of weather conditions. During 1997, the Company
transported for its own account an average of approximately 24,100 barrels of
petroleum products per day through this pipeline. The Company also owns and
operates KPL, a common carrier pipeline and marine dock facility, which assures
the Company of uninterrupted use of the dock and pipeline for unloading crude
oil feedstocks and loading product inventory on tankers and barges. During 1997,
the Company transported for its own account approximately 49,700 barrels of
crude oil per day and 37,300 barrels of refined products per day through the KPL
facilities.
For further information on transportation in Alaska, see "-- Government
Regulation and Legislation -- Environmental Controls."
HAWAII
Crude oil is transported to Hawaii by tankers and discharged through a
single point mooring terminal ("SPM") about 1.5 miles offshore from the Hawaii
Refinery. The Company charters barges and tugs to transport petroleum products
to its customers in the Hawaiian Islands and a foreign flag vessel, the Carla
Hills, to transport diesel fuel, jet fuel and gasoline to customers in American
Samoa, and fuel oil to a customer in Tahiti. The Carla Hills is also used to
transport product imports and exports between Hawaii and the Far East. The
Company also is a party to two Contracts of Affreightment with independent
parties to charter vessels to meet its transportation requirements for crude oil
and clean products.
Three underwater pipelines connect the SPM to the Hawaii Refinery to allow
crude oil and products to be transferred to the Hawaii Refinery and to load
products from the Hawaii Refinery to ships and barges. Refined products are
distributed to customers on the island of Oahu through a pipeline system with
connections to the military at several locations, to commercial customers via
terminals at Honolulu International Airport and Honolulu Harbor, and by barge to
facilities on the outer islands of Maui, Kauai and Hawaii. Four product
pipelines connect the Hawaii Refinery to Barbers Point Harbor which is 2.5 miles
away. The Barbers Point Harbor is able to accommodate barges and product tankers
up to 800 feet in length and helps relieve traffic at the SPM.
WASHINGTON
Crude oils from Canada are received through the 24-inch Transmountain
Pipeline which originates in Edmonton, Canada. Other crudes, including ANS, are
received through the Washington Refinery's ship dock. Both the pipeline and the
ship dock are each capable of providing almost 100% of the Washington Refinery's
feedstock needs.
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Over 90% of the Washington Refinery's clean products (gasoline, jet fuel
and diesel) leave via Olympic Pipeline. Olympic serves the Seattle area with
16-inch and 20-inch lines and continues to Portland with a 14-inch line. Over
20% of the Washington Refinery's clean product is delivered (via Olympic) to
Chevron, for which Shell receives products in California. A small amount of
Shell branded gasoline is delivered over the neighboring Texaco Washington
Refinery's truck rack and jet fuel is occasionally shipped by barge. The
Washington Refinery has the capability to move significant volumes of all clean
products over the ship dock. All of the fuel oil production is shipped by water.
Propane is shipped by both truck and rail.
REFINING AND MARKETING STATISTICS
The following table summarizes the Company's refining and marketing
operations for the fiscal years indicated and three months ended March 31, 1998:
<TABLE>
<CAPTION>
THREE MONTHS
FISCAL YEARS(a) ENDED
------------------------ MARCH 31,
1995 1996 1997 1998
------ ------ ------ ------------
<S> <C> <C> <C> <C>
REFINERY THROUGHPUT (thousands of bpd)
Alaska Refinery.................................. 50.6 47.5 50.2 56.1
Hawaii Refinery.................................. 90.6 86.7 88.7 86.4
Washington Refinery.............................. 104.9 114.5 113.0 114.6
REFINED PRODUCTS MANUFACTURED (thousands of bpd)
Alaska Refinery --
Gasoline and gasoline blendstocks.............. 14.3 12.8 12.8 15.2
Middle distillates, including jet fuel and
diesel fuel................................. 20.7 20.0 21.6 25.2
Heavy oils and residual products............... 14.5 13.7 14.8 15.1
Other.......................................... 2.5 2.6 2.3 2.2
------ ------ ------ ------
Total Alaska Refinery..................... 52.0 49.1 51.5 57.7
------ ------ ------ ------
Hawaii Refinery --
Gasoline and gasoline blendstocks.............. 22.1 19.0 22.0 19.8
Middle distillates, including jet fuel and
diesel fuel................................. 39.3 39.6 40.4 40.3
Heavy oils and residual products............... 27.1 25.9 24.3 23.4
Other.......................................... 3.2 2.6 2.9 3.5
------ ------ ------ ------
Total Hawaii Refinery..................... 91.7 87.1 89.6 87.0
------ ------ ------ ------
Washington Refinery --
Gasoline and gasoline blendstocks.............. 60.3 64.2 62.1 63.2
Middle distillates, including jet fuel and
diesel fuel................................. 24.1 28.9 28.3 29.9
Heavy oils and residual products............... 14.9 15.3 17.1 16.2
Other.......................................... 9.6 10.4 9.9 10.0
------ ------ ------ ------
Total Washington Refinery................. 108.9 118.8 117.4 119.3
------ ------ ------ ------
Total Refined Products Manufactured....... 252.6 255.0 258.5 264.0
====== ====== ====== ======
NUMBER OF STATIONS SELLING THE REFINERIES'
GASOLINE(b)
Alaska --
Company-operated............................... 32 33 35 35
Branded jobbers and dealers.................... 99 126 129 125
Unbranded jobbers and dealers.................. 28 29 28 25
Pacific Northwest -- branded jobbers and
dealers........................................ 10 18 30 33
Hawaii -- Company-operated....................... 28 28 28 30
Hawaii -- Dealer-operated........................ 1 2 2 2
------ ------ ------ ------
Total Stations............................ 198 236 252 250
====== ====== ====== ======
</TABLE>
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- ---------------
(a) Amounts for Tesoro and Shell Washington are for fiscal years ended December
31. Amounts for BHP Hawaii are for fiscal years ended May 31.
(b) Branded gasoline stations sell the Alaska Refinery's gasoline under the
"Tesoro Alaska" name in Alaska, Oregon and Washington (191 stations as of
March 31, 1998) and under the "Union 76" name in Southeast Alaska (two
stations as of March 31, 1998). Stations that sell the Company's gasoline
under a different name are considered unbranded. Branded Gasoline stations
sell the Hawaii Refinery's gasoline under the "Gas Express" name in Hawaii.
As of March 31, 1998 the Company operated 38 convenience stores located in
Alaska, 35 of which sell gasoline.
EXPLORATION AND PRODUCTION
OVERVIEW
The Company's Exploration and Production segment is engaged in the
exploration for, and development and production of, natural gas and oil onshore
in Texas, Louisiana and Bolivia. This segment also includes the transportation
of natural gas, including the Company's production, to common carrier pipelines
in South Texas. During 1997, the Company increased its worldwide net proved
reserves by 39% to 517 Bcfe of natural gas. Worldwide net production of natural
gas and oil averaged 109 MMcfe per day during 1997 and increased to
approximately 130 MMcfe per day in March 1998.
In the U.S., the Company has made significant progress in diversifying its
operations to areas other than the Bob West Field in South Texas. The Company's
U.S. production from fields other than the Bob West Field rose to 50% of its
total U.S. production in January 1998, as compared to 7% at year-end 1996.
During the past two years, the Company has acquired approximately 120,000 net
undeveloped acres in the U.S., bringing its total to approximately 133,000 net
undeveloped U.S. acres at December 31, 1997. During 1996 and 1997, the
Exploration and Production segment purchased interests in the Frio/Vicksburg
Trend and the Wilcox Trend in South Texas, in the Val Verde Basin in Southwest
Texas and in the East Texas Basin. By January 1998, the Company served as
operator of 44% of its U.S. net production, compared to 5% at year-end 1996.
During 1997, the Company's U.S. net proved reserve volumes increased 27% to 150
Bcfe and net production averaged 87 MMcfe per day. The Company participated in
the completion of nine gross development wells and eight gross exploratory wells
in 1997, with seven gross wells drilling at year-end.
In Bolivia, the Company operates under four contracts with the Bolivian
government to explore for and produce hydrocarbons. The Company's Bolivian
natural gas production is sold under contract to the Bolivian government for
export to Argentina. The majority of the Company's natural gas and oil reserves
in Bolivia are shut-in awaiting access to gas-consuming markets which is
expected to be provided by a 1,900-mile pipeline from Bolivia to Brazil.
Pipeline construction began in 1997 and first gas deliveries are expected in
early 1999. Upon completion of the pipeline, the Company will face intense
competition from major and independent natural gas companies operating in
Bolivia for an additional share of the contractual volumes to be exported to
Brazil. See "Management's Discussion and Analysis of Financial Condition and
Results of Operations -- Exploration and Production -- Bolivia." In July 1997,
the Company acquired the interests of its former joint venture participant,
increasing its net proved reserve volumes in Bolivia by 35%. During 1997, the
Company's Bolivian net proved reserve volumes increased in total by 45% to 366
Bcfe and net production averaged 23 MMcfe per day.
WORLDWIDE RESERVE REPLACEMENT AND COSTS OF ADDING RESERVES
In 1997, the Company's worldwide net proved reserve additions included 156
Bcfe from discoveries, extensions and purchases of proved properties (89 Bcfe in
Bolivia and 67 Bcfe domestically) and 30 Bcfe from upward revisions of previous
estimates. Excluding revisions, 156 Bcfe were added for a 390% replacement of 40
Bcfe of production. Additions were realized with a 74% drilling success rate
during 1997, reflecting an 82% success rate on 11 development wells and a 67%
success rate on 12 exploratory wells. The Company's three-year worldwide average
cost of adding these reserves was $0.43 per Mcfe. Domestically, 67 Bcfe were
added through discoveries, extensions and acquisitions for a 209% replacement of
32 Bcfe of production. In Bolivia, 89 Bcfe were added through an acquisition, a
more than tenfold replacement of eight Bcfe of production. The
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<PAGE> 77
three-year average cost of adding reserves was $0.85 per Mcfe in the U.S. and
$0.14 per Mcfe in Bolivia. See Note N of Notes to Tesoro's Consolidated
Financial Statements.
UNITED STATES
RESERVES
The following table shows the estimated net proved reserves, based on
evaluations audited by Netherland, Sewell & Associates, Inc., and gross
producing wells for each of the Company's U.S. fields:
<TABLE>
<CAPTION>
DECEMBER 31,
DECEMBER 31, 1997 1996
------------------------------------------ -------------
NET PROVED NET PROVED
PRESENT VALUE GROSS GAS RESERVES GAS RESERVES
OF PROVED PRODUCTIVE ------------- -------------
FIELD LOCATION TREND RESERVES(a) WELLS BCFE % BCFE %
----- -------- ----- ------------- ---------- ------ ---- ------ ----
($ THOUSANDS)
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Bob West South Texas Wilcox $ 74,659 63 59.0 39% 88.0 75%
Los Indios South Texas Frio/Vicksburg 11,751 26 15.3 10 16.8 14
Vinegarone East Southwest Texas Val Verde 16,457 4 14.3 10 -- --
Kent Bayou South Louisiana Frio/Vicksburg 13,749 1 10.5 7 -- --
Oak Hill East Texas East Texas Basin 5,389 5 9.9 7 -- --
Berry R. Cox South Texas Wilcox 14,426 5 8.6 6 2.9 3
La Reforma South Texas Frio/Vicksburg 8,558 18 7.7 5 2.8 2
Woodlawn East Texas East Texas Basin 3,883 2 6.5 4 -- --
Carthage East Texas East Texas Basin 2,740 -- 4.7 3 -- --
Other Various Various 15,883 54 13.9 9 7.4 6
-------- --- ----- --- ----- ---
$167,495 178 150.4 100% 117.9 100%
======== === ===== === ===== ===
</TABLE>
- ---------------
(a) Represents the discounted future net cash flows before income taxes. See
Note N of Notes to Tesoro's Consolidated Financial Statements for
additional information regarding the Company's proved reserves and
standardized measure.
Wilcox Trend. The Company has 23,088 net acres, including 17,147 net
undeveloped acres, under lease in the Wilcox Trend. Approximately 52% (78.4
Bcfe) of the Company's U.S. net proved reserve volumes are located in 11
producing fields in this trend, including the Bob West Field, the Company's
largest U.S. field. The Wilcox Trend extends from Northern Mexico through South
Texas into the other Gulf Coast states. Multiple pay sands exist within the
Wilcox Trend, where extensive faulting has trapped hydrocarbons in numerous
producing zones.
Frio/Vicksburg Trend. The Company has 7,667 net acres, including 2,897 net
undeveloped acres, under lease in the Frio/Vicksburg Trend. Approximately 24%
(36.5 Bcfe) of the Company's U.S. net proved reserve volumes are located in
eight producing fields in this trend, primarily the Los Indios, La Reforma and
Kent Bayou Fields. The Frio/Vicksburg Trend lies between the Gulf Coast
shoreline and the Wilcox Trend.
East Texas Basin. The Company has 16,988 net acres, including 14,064 net
undeveloped acres, under lease in the East Texas Basin. The undeveloped acreage
is located on prospects in the Cotton Valley Pinnacle Reef play and on prospects
targeting various Cretaceous aged objectives. The Company is currently acquiring
3-D seismic surveys to evaluate its acreage holdings. Approximately 14% (21.3
Bcfe) of the Company's U.S. net proved reserve volumes are in this basin, which
is located in the northeastern part of Texas.
Val Verde Basin. The Company has 94,761 net acres, primarily undeveloped,
under lease in the Val Verde Basin in Edwards and Val Verde Counties, Texas. As
of December 31, 1997, approximately 10% (14.3 Bcfe) of the Company's U.S. net
proved reserve volumes are in this basin, which is located in the southwestern
part of Texas. In April 1998, the Company completed a new well which
significantly increased proved reserves and production in this basin.
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<PAGE> 78
GAS GATHERING AND TRANSPORTATION
The Company owns a 70% interest in the Starr County Gathering System, which
consists of two 10-inch diameter pipelines and one 20-inch diameter pipeline
that transport natural gas eight miles from the Bob West Field in South Texas to
common carrier pipeline facilities. In addition, the Company owns a 50% interest
in the 20-inch diameter Starr-Zapata Pipe Line, which transports natural gas 26
miles from the Starr County Gathering System to a market hub at Fandango, Texas.
The Company does not operate either pipeline. During 1997, gross throughput
averaged 169 MMcf per day for both the Starr County Gathering System and the
Starr-Zapata Pipe Line, with approximately 50% of the throughput consisting of
the Company's working interest of Bob West Field production. The Starr County
Gathering System receives a transportation fee of $0.06 per Mcf and the
Starr-Zapata Pipe Line receives a fee of $0.07 per Mcf for volumes transported.
MARKETING
The Company's U.S. natural gas production is sold on the spot market and
under short-term contracts with a variety of purchasers, including intrastate
and interstate pipelines, their marketing affiliates, independent marketing
companies and other purchasers who have the ability to move the gas under firm
transportation or interruptible agreements. Prices for the Company's natural gas
production are subject to regional discounts or premiums tied to regional spot
market prices.
U.S. ACREAGE AND PRODUCTIVE WELLS
The Company holds its U.S. acreage through oil and natural gas leases and
lease options. The leases have a variety of primary terms and may require delay
rentals to continue the primary term if not productive. The leases may be
surrendered by the operator at any time for various reasons, which may include
cessation of production, fulfillment of commitments, or failure to make timely
payment of delay rentals. The following tables set forth the Company's U.S.
gross and net acreage and productive wells at December 31, 1997:
<TABLE>
<CAPTION>
UNDEVELOPED ACREAGE DEVELOPED ACREAGE
------------------- -----------------
LOCATION GROSS NET GROSS NET
-------- -------- -------- ------- -------
<S> <C> <C> <C> <C>
Val Verde Basin, Southwest Texas................. 98,466 94,401 480 360
East Texas Basin, East Texas..................... 56,278 14,064 3,303 2,924
Wilcox Trend, South Texas........................ 37,986 17,147 19,349 5,941
Frio/Vicksburg Trend, South Texas................ 4,034 2,017 10,556 4,538
Frio/Vicksburg Trend, South Louisiana............ 880 880 315 232
------- ------- ------ ------
Total Leased Acres..................... 197,644 128,509 34,003 13,995
Fee Acres, Various Locations..................... 15,838 4,352 338 325
------- ------- ------ ------
Total Acres............................ 213,482 132,861 34,341 14,320
======= ======= ====== ======
</TABLE>
<TABLE>
<CAPTION>
GAS WELLS OIL WELLS
------------ -----------
GROSS NET GROSS NET
----- ---- ----- ---
<S> <C> <C> <C> <C>
Productive Wells(a)........................................ 168 86.9 10 5.4
</TABLE>
- ---------------
(a) Includes three gross (1.6 net) gas wells and two gross (1.0 net) oil wells
with multiple completions. At December 31, 1997, the Company was
participating in the drilling of seven gross (6.3 net) wells.
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<PAGE> 79
U.S. OPERATING STATISTICS
The following table summarizes the Company's U.S. exploration and
production activities for the years ended December 31, 1995, 1996 and 1997 and
three months ended March 31, 1998:
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31, THREE MONTHS
--------------------------- ENDED MARCH 31,
1995 1996 1997 1998
------- ------ ------ ---------------
<S> <C> <C> <C> <C>
Average Daily Net Production:
Natural gas (Mcf)..................... 114,490 87,654 86,052 99,135
Oil (barrels)......................... 1 27 118 173
Total (Mcfe).......................... 114,496 87,816 86,760 100,173
Exploratory Wells Drilled(a):
Productive -- gross................... 5.0 4.0 8.0 3.0
Productive -- net..................... 1.5 1.7 6.3 2.5
Dry holes -- gross.................... 4.0 2.0 4.0 4.0
Dry holes -- net...................... 2.1 1.0 2.9 3.3
Development Wells Drilled(a):
Productive -- gross................... 17.0 15.0 9.0 3.0
Productive -- net..................... 9.7 6.3 5.1 2.3
Dry holes -- gross.................... -- 1.0 2.0 --
Dry holes -- net...................... -- 0.5 1.0 --
</TABLE>
- ---------------
(a) All of the Company's drilling is performed by independent drilling
contractors.
For further information regarding the Company's U.S. exploration and
production operations, see Notes B, C and N of Notes to Tesoro's Consolidated
Financial Statements.
BOLIVIA
The Company's Bolivian exploration, development and production operations
are located in the Chaco Basin in southern Bolivia near the border of Argentina.
The Company has discovered six fields in Bolivia since 1976, five of which have
currently estimated proved reserves totaling 366 Bcfe at December 31, 1997. The
Company intends to complete additional seismic studies and appraisal wells
before assigning proved reserves to the sixth field. With production of 37 MMcfe
per day (gross) in 1997, the Company is one of the largest operators in Bolivia.
The Company estimates that it currently could produce from its existing proved
developed producing reserve base approximately 120 MMcfe per day (gross) if
ready markets were available. The Company holds four shared risk contracts with
YPFB, the Bolivian governmental agency responsible for administration of these
contracts, covering a total of 879,938 gross acres in Block 18 and Block 20.
ACQUISITION
In July 1997, the Company purchased the interests held by its former joint
venture participant in the then existing two contract blocks, consisting of a
25% interest in Block 18 and a 27.4% interest in Block 20. Upon completion of
this purchase, the Company held a 100% interest in both blocks, subject to a
farmout agreement discussed below. The purchase price was approximately $20
million, which included working capital and assumption of certain liabilities.
The Company's net proved Bolivian reserve volumes increased by approximately 35%
as a result of this acquisition.
BOLIVIAN HYDROCARBONS LAW
In 1996, a new Hydrocarbons Law was passed by the Bolivian government that
significantly impacts the Company's operations in Bolivia. The new law, among
other matters, granted the Company the option to convert its Contracts of
Operation to new shared risk contracts. On November 6, 1997, the Company
completed the conversion of its Contracts of Operation into four shared risk
contracts. The new contracts, which have an effective date of July 29, 1996,
extend the Company's term of operation, provide more
76
<PAGE> 80
favorable acreage relinquishment terms and provide for a more favorable fiscal
regime of royalties and taxes. The new contract for Block 18 is extended to the
year 2017. The new contracts for Block 20 are extended to the year 2018 for
Block 20-Los Suris, which is in the development phase, and to the year 2029 for
Block 20-West and Block 20-East, which are in the exploration phase.
FARMOUT AGREEMENT
A farmout agreement executed June 19, 1997, between the Company and Total
Exploration Production Bolivie S.A. ("Total"), an affiliate of Total S.A.,
covers a portion of Block 20-West. Pursuant to the farmout agreement, Total
established a financial guarantee to the Bolivian government to guarantee the
performance of exploration work on Block 20-West. Total has the right to drill,
at its sole cost, two exploratory wells to earn a 75% interest in the farmout
area which consists of 315,000 acres of Block 20-West. If Total drills only one
well, Total will earn a 37.5% interest in the farmout area. On December 31,
1997, the Company assigned a 75% interest and operatorship in the farmout area
to Total, subject to reversion if Total does not drill two wells.
YPF AND YPFB CONTRACT
The Company is currently selling all of its natural gas production from
Block 18 to YPFB, which in turn sells the natural gas to YPF, a publicly-held
company based in Argentina. Currently, the Company's sales of natural gas are
based on the volume and pricing terms in the contract between YPFB and YPF. The
Company has historically provided approximately 20% of the contract volumes
required by YPF. The contract to sell gas to YPF expired March 31, 1997, and a
contract extension was signed effective April 1, 1997, extending the contract
term two years to March 31, 1999, with an option to extend the contract a
maximum of one additional year if the pipeline being constructed from Bolivia to
Brazil is not complete. In the contract extension, YPF negotiated an 11%
reduction in the minimum contract volume that it is required to import from
Bolivia, which in turn resulted in a corresponding 11% reduction of the
Company's minimum contract volume to 36.9 MMcf per day gross (26.2 net). The
contract gas prices fluctuate because they are linked to a monthly average fuel
oil price posted in the New York spot market.
ACCESS TO NEW MARKETS
A lack of market access has constrained natural gas production in Bolivia.
With little internal gas demand, all of the Company's Bolivian natural gas
production is sold under contract to the Bolivian government for export to
Argentina. Major developments in South America indicate that new markets will
open for the Company's production. Construction of a new 1,900-mile pipeline
that will link Bolivia's extensive gas reserves with markets in Brazil commenced
in 1997 and is expected to be operational in early 1999. The owners of the new
pipeline include Petroleo Brasileiro S.A. (the Brazilian state oil company),
other Brazilian investors, Enron Corp., Shell International Gas Ltd., British
Gas PLC, El Paso Energy Corp., BHP, and Bolivian pension funds. When completed,
the new pipeline will have a capacity of approximately one billion cubic feet
("Bcf") per day. It is anticipated that each producer's share of the contractual
volumes will be allocated by YPFB according to a number of factors, including
each producer's reserve volumes and production capacity. The Company's 1998
capital budget includes plans to drill three development wells (gross) and two
exploratory wells (gross) which may increase its productive capacity.
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<PAGE> 81
RESERVES
The table below shows the estimated proved reserves, based on evaluations
prepared by Netherland, Sewell & Associates, Inc., and productive wells for each
of the Company's Bolivian fields. Each of the following fields is operated by
the Company:
<TABLE>
<CAPTION>
DECEMBER 31,
DECEMBER 31, 1997 1996
-------------------------------------------------------------------- -----------------
NET PROVED RESERVES
-----------------------------------
OIL
PRODUCTIVE (MILLIONS OF GAS TOTAL PV-10 AFTER PV-10 AFTER
FIELD BLOCK WELLS BARRELS) (BCF) (BCFE) % BOLIVIAN TAXES(a) BOLIVIAN TAXES(a)
----- ----- ---------- ------------ ----- ------ --- ----------------- -----------------
($ THOUSANDS) ($ THOUSANDS)
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Palo Marcado......... 20 2 2.0 140.1 152.1 42% $ 38,871 $24,667
Los Suris............ 20 2 1.1 97.6 104.2 28 32,685 13,135
Escondido............ 18 4 1.6 78.0 87.6 24 23,926 23,330
La Vertiente......... 18 4 0.5 19.0 22.0 6 5,971 3,090
Taiguati............. 18 1 -- 0.4 0.4 -- -- 221
-- --- ----- ----- --- -------- -------
13 5.2 335.1 366.3 100% $101,453 $64,443
== === ===== ===== === ======== =======
</TABLE>
- ---------------
(a) Represents the discounted future net cash flows after Bolivian taxes. See
Note N of Notes to Tesoro's Consolidated Financial Statements for additional
information regarding the Company's proved reserves and standardized
measure.
BOLIVIAN ACREAGE AND PRODUCTIVE WELLS
The following table sets forth the Company's Bolivian gross and net acreage
and productive wells at December 31, 1997:
<TABLE>
<CAPTION>
GROSS NET
------- -------
<S> <C> <C>
Acreage:
Developed................................................. 92,625 92,625
Undeveloped............................................... 787,313 551,063
Productive Gas Wells(a)................................... 13 13
</TABLE>
- ---------------
(a) Included in productive gas wells are five gross (five net) wells with
multiple completions. The Company has no producing oil wells in Bolivia.
BOLIVIA OPERATING STATISTICS
The following table summarizes the Company's Bolivian exploration and
production activities for the years ended December 31, 1995, 1996 and 1997 and
the three months ended March 31, 1998:
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31, THREE MONTHS
------------------------ ENDED MARCH 31,
1995 1996 1997 1998
------ ------ ------ ---------------
<S> <C> <C> <C> <C>
Average Daily Net Production:
Natural gas (Mcf)......................... 18,650 20,251 19,537 22,769
Condensate (barrels)...................... 567 584 518 816
Total (Mcfe).............................. 22,052 23,755 22,645 27,665
Exploratory Wells Drilled:
Productive -- gross....................... 1.0 2.0 -- --
Productive -- net......................... 0.7 1.5 -- --
Dry holes -- gross........................ -- -- -- --
Dry holes -- net.......................... -- -- -- --
</TABLE>
78
<PAGE> 82
For further information regarding the Company's Bolivian operations, see
Notes B, C and N of Notes to Tesoro's Consolidated Financial Statements.
MARINE SERVICES
OVERVIEW
The Company's Marine Services segment markets and distributes a broad range
of products, including diesel fuel, lubricants, chemicals and supplies, and
provides logistical support services to the marine and offshore exploration and
production industries operating in the Gulf of Mexico. These operations were
conducted in 1997 through a network of 18 marine and two land terminals located
on the Texas Gulf Coast in Galveston, Freeport, Harbor Island, Port O'Connor,
Sabine Pass, Channelview and Houston and along the Louisiana Gulf Coast in
Cameron, Intracoastal City, Berwick, Venice, Port Fourchon, Amelia and Harahan.
The marine terminals are generally deep water and are bulkheaded and dredged to
provide easy access to vessels receiving products for delivery to customers.
Products are delivered offshore aboard vessels owned or chartered by customers,
which include companies engaged in oil and gas exploration and production,
seismic evaluation, offshore construction and other drilling-related businesses.
In January 1998, the Marine Services operations were expanded to include the
operations of three terminals located on the U.S. West Coast, previously
operated by the Company's Refining and Marketing segment (see
"-- Marketing -- Pacific Northwest" discussed above).
FUELS AND LUBRICANTS
Fuels and lubricants, which are used by operations such as offshore
drilling rigs, offshore production and transmission platforms and various ships
and equipment engaged in seismic surveys, are marketed and distributed from the
Company's terminals. These terminals and a fleet of seven tugboats (including
four owned by the Company) and 14 barges (including 12 owned by the Company)
serve offshore workboats, tugboats and barges using the Intracoastal Canal
System, as well as ships entering the ports of Houston, New Orleans, Lake
Charles, Corpus Christi and Port Arthur. The Company obtains its supply of fuel
from refiners in the Gulf Coast area. Total gallons of fuel, primarily diesel
fuel, sold by Marine Services amounted to 112.5 million, 142.7 million and 156.4
million in the years 1995, 1996 and 1997, respectively. During the three months
ended March 31, 1997 and 1998, total gallons of fuel sold by Marine Services
were approximately 39.6 million and 47.9 million, respectively.
The Company is a distributor of major brands of marine lubricants and
greases, offering a full spectrum of grades. Lubricants are delivered to
customers by trucks or tugs and barges. Total gallons of lubricants sold by
Marine Services amounted to 2.5 million, 2.3 million and 2.7 million for the
years ended December 31 1995, 1996 and 1997, respectively. For the three months
ended March 31, 1997 and 1998, total gallons of lubricants were 0.7 and 1.7
million, respectively.
LOGISTICAL SERVICES
Through many of its terminals, the Company provides full-service
shore-based support for offshore drilling rigs and production platforms. These
quayside services provide cranes, forklifts and loading docks for supply boats
serving the offshore exploration and production industry. In addition, the
Company provides long-term parking for offshore workers, helicopter landing pads
and office space with living quarters. The Company's terminals also serve as
delivery points for drilling products, primarily mud, by providing warehousing,
blending, inventory control and delivery services. In the years 1995, 1996 and
1997, revenues from these logistical services were $0.6 million, $8.7 million
and $11.3 million, respectively. In the three months ended March 31, 1997 and
1998, revenues from logistical services were $3.0 million and $2.9 million,
respectively.
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<PAGE> 83
COMPETITION AND OTHER
The petroleum industry is highly competitive in all phases, including the
refining of crude oil, the marketing of refined petroleum products, the search
for and development of oil and gas reserves and the marine services business.
The industry also competes with other industries that supply the energy and fuel
requirements of industrial, commercial and individual consumers. The Company
competes with a substantial number of major integrated oil companies and other
companies having materially greater financial and other resources than the
Company. These competitors have a greater ability to bear the economic risks
inherent in all phases of the industry. In addition, unlike the Company, many of
its competitors produce large volumes of crude oil which can then be used in
connection with their refining operations. The North American Free Trade
Agreement has further streamlined and simplified procedures for the importation
and exportation of natural gas among Mexico, the United States and Canada. These
changes are likely to enhance the ability of Canadian and Mexican producers to
export natural gas and other products to the United States, thereby further
increasing competition for domestic sales.
The refining and marketing businesses are highly competitive, with price
being the principal factor in competition. In the refining industry, the Alaska
Refinery competes primarily with other refineries in Alaska and on the U.S. West
Coast. The Company's refining competition in Alaska includes two refineries
situated near Fairbanks and one refinery situated near Valdez. The Company
estimates that such other refineries have a combined capacity to process
approximately 184,000 bpd of crude oil. The Company believes that ANS crude oil
is the only feedstock used in these competing refineries. After processing the
crude oil and removing the lighter-end products, which the Company believes
represent approximately 30% of each barrel processed, these refiners are
permitted, because of their direct connection to the TAPS, to return the
remainder of the processed crude back into the pipeline system as "return oil"
in consideration for a fee, thereby eliminating their need to market residual
products. The Alaska Refinery is not directly connected to the TAPS, and the
Company, therefore, cannot return its residual products to the TAPS. The
Company's refining competition from the U.S. West Coast includes many large,
integrated oil companies that do business in Alaska and have materially greater
financial and other resources. The Hawaii Refinery competes primarily with one
other refinery in Hawaii which is also located at Kapolei and which has a rated
capacity of 55,000 bpd of crude oil. Historically, the other refinery in Hawaii
produced lower volumes of jet fuel than BHP Hawaii. The Washington Refinery
competes with several refineries on the U.S. West Coast, including refineries
which are larger than the Washington Refinery and which are owned by companies
substantially larger than the Company.
The Company is a major producer and distributor of gasoline in Alaska and
Hawaii through a large network of Company-operated stations and branded and
unbranded dealers and jobbers. The Company is also a supplier to a major oil
company through a product exchange agreement, whereby gasoline in Alaska is
provided in exchange for gasoline delivered to the Company on the U.S. West
Coast. In addition, the Company is a supplier to a major oil company in Hawaii
through a gasoline sales agreement. Competitive factors affecting the marketing
of gasoline in Alaska and Hawaii include such factors as product price, location
and quality together with station appearance and brand-name identification. The
Company competes with other petroleum companies, distributors and other
developers for new locations. The Company believes it is in a position to
compete effectively as a marketer of gasoline in Alaska and Hawaii because of
its strong presence in these markets.
The Company's jet fuel sales in Alaska are concentrated in Anchorage, where
it is one of the principal suppliers to the Anchorage International Airport,
which is a major hub for air cargo traffic between manufacturing regions in the
Far East and consuming regions in the United States and Europe. In Hawaii, jet
fuel sales are concentrated in Honolulu, where the Company is the principal
supplier to the Honolulu Airport. The Company also serves four airports on other
islands in Hawaii. The Company sells its diesel fuel primarily on a wholesale
basis. Refined products from foreign sources also compete for distillate markets
in the Company's Alaskan market area.
The Company's Pacific Northwest marketing business is primarily a
distribution business selling to independent dealers and jobbers. In addition,
the Company sells its gasoline through 30 branded gasoline
80
<PAGE> 84
stations in the Pacific Northwest. The Company competes against independent
marketing companies and integrated oil companies when engaging in these
marketing operations.
The exploration for and production of natural gas and oil is highly
competitive in both the United States and in South America. In seeking to
acquire producing properties, new leases, concessions and exploration prospects,
the Company faces competition from both major and independent oil and natural
gas companies. Many of these competitors have financial and other resources
substantially in excess of those available to the Company and, therefore, may be
better positioned to acquire and develop prospects, hire personnel and market
production. The larger competitors may also be able to better respond to factors
that influence the market for oil and natural gas production, such as changes in
worldwide prices and governmental regulations. Such factors are beyond the
control of the Company.
The Company's natural gas production in Bolivia is sold under contract to
YPFB, which in turn exports the natural gas to Argentina, as the internal demand
for natural gas in Bolivia is limited. The Company believes that the completion
of a 1,900-mile pipeline from Bolivia to Brazil will provide access to larger
gas-consuming markets. Upon completion of this pipeline, the Company will face
intense competition from major and independent natural gas companies operating
in Bolivia for a share of the contractual volumes to be exported to Brazil. It
is anticipated that each producer's share of the contractual volumes will be
allocated by YPFB according to a number of factors, including each producer's
reserve volumes and production capacity. Although the Company expects gas
deliveries on the pipeline to begin in early 1999, there can be no assurance
that the pipeline will be operational by such date. With the exception of the
volumes currently under contract with the Bolivian government, the Company
cannot be assured of the amount of additional volumes that will be exported to
Brazil upon completion of the pipeline.
Demand for services and products offered by the Company's Marine Services
segment is closely related to the level of oil and gas exploration, development
and production in the Gulf of Mexico. Various factors, including general
economic conditions, demand for and prices of natural gas, availability of
equipment and materials and government regulations and energy policies cause
exploration and development activity to fluctuate and directly impact the
revenues of the Marine Services segment. Management believes that the principal
competitive factors affecting the Marine Services operations are location of
facilities, availability of logistical support services, experience of personnel
and dependability of service. The market for the Marine Services segment's
products and services, particularly diesel fuel, is price sensitive. The Company
competes with several independent operations, and in certain locations with one
or more major mud companies who maintain their own marine terminals.
A portion of the Company's operations are conducted in foreign countries
where the Company is also subject to risks of a political nature and other risks
inherent in foreign operations. The Company's operations outside the United
States in recent years have been, and in the future may be, materially affected
by host governments through increases or variations in taxes, royalty payments,
export taxes and export restrictions and adverse economic conditions in the
foreign countries, the future effects of which the Company is unable to predict.
GOVERNMENT REGULATION AND LEGISLATION
UNITED STATES
Natural Gas and Oil Regulations. Historically, all domestic natural gas
sold in so-called "first sales" was subject to federal price regulations under
the Natural Gas Policy Act of 1978 ("NGPA"), the Natural Gas Act ("NGA") and the
regulations and orders issued by the Federal Energy Regulatory Commission
("FERC") in implementing such Acts. Under the Natural Gas Wellhead Decontrol Act
of 1989, all remaining federal natural gas wellhead pricing and sales regulation
was terminated on January 1, 1993.
The FERC also regulates interstate natural gas pipeline transportation
rates and service conditions, which affect the marketing of gas produced by the
Company, as well as the revenues received by the Company for sales of such gas.
Since the latter part of 1985, through a series of orders, the FERC has
endeavored to make natural gas transportation more accessible to gas buyers and
sellers on an open and non-discriminatory basis,
81
<PAGE> 85
and the FERC's efforts have significantly altered the marketing and pricing of
natural gas. These orders have gone through various permutations, but have
generally remained intact as promulgated. The FERC considers these changes
necessary to improve the competitive structure of the interstate natural gas
pipeline industry and to create a regulatory framework that will put gas sellers
into more direct contractual relations with gas buyers than has historically
been the case. The result of the changes has brought to an end the interstate
pipelines' traditional role as wholesalers of natural gas in favor of providing
only gathering, transportation and storage services for others which will buy
and sell natural gas. Although these orders do not directly regulate gas
producers, such as the Company, they are intended to foster increased
competition within all phases of the natural gas industry. It is unclear what
impact, if any, increased competition within the natural gas industry will have
on the Company and its gas sales efforts. Several aspects of these orders are
still being reviewed by the courts and the FERC. It is not possible to predict
what, if any, effect these proceedings will have on the Company. The Company
does not believe, however, that it will be affected any differently than other
gas producers or marketers with which it competes.
The oil and gas exploration and production operations of the Company are
subject to various types of regulation at the state and local levels. Such
regulation includes requiring drilling permits and the maintenance of bonds in
order to drill or operate wells, the regulation of the location of wells, the
method of drilling and casing of wells and the surface use and restoration of
properties upon which wells are drilled, and the plugging and abandoning of
wells. The operations of the Company are also subject to various conservation
regulations, including regulation of the size of drilling and spacing units or
proration units, the density of wells that may be drilled in a given area and
the unitization or pooling of oil and gas properties. In this regard, some
states allow the forced pooling or integration of lands and leases. In addition,
state conservation laws establish maximum rates of production from oil and gas
wells, generally prohibit the venting or flaring of gas and impose certain
requirements regarding the ratability of production. The effect of these
regulations is to limit the amounts of crude oil, condensate and natural gas the
Company can produce from its wells and the number of wells or the locations at
which the Company can drill.
Additional proposals and proceedings that might affect the natural gas
industry are considered from time to time by Congress, the FERC, state
regulatory bodies and the courts. The Company cannot predict when or if any such
proposals might become effective, or their effect, if any, on the Company's
operations.
Environmental Controls. Federal, state, area and local laws, regulations
and ordinances relating to the protection of the environment affect all
operations of the Company to some degree. An example of a federal environmental
law that will require operational additions and modifications is the Clean Air
Act, which was amended in 1990. While the Company believes that its facilities
generally are in substantial compliance with current regulatory standards for
air emissions, over the next several years the Company's facilities will be
required to comply with the new requirements being adopted and promulgated by
the EPA and the states in which the Company operates. These regulations will
necessitate the installation of additional controls or other modifications or
changes in use for certain emission sources at the Alaska, Hawaii and Washington
Refineries. Specifics as to the cost of these requirements, and the necessity
for changes at other Company facilities, are still being determined. As part of
these requirements, the Alaska, Hawaii and Washington Refineries, as well as
some other Company facilities submitted applications for Clean Air Act Amendment
Title V permits. Each application has been deemed complete by their respective
states and will undergo technical review in 1998. The Company believes it can
comply with these new requirements, and in some cases already has done so,
without adversely affecting operations.
The passage of the Federal Clean Air Act Amendments of 1990 prompted
adoption of regulations by the state of Alaska obligating the Company to produce
oxygenated gasoline for delivery to the Anchorage and Fairbanks, Alaska markets
starting on November 1, 1992. Controversies surrounding the potential health
effects in Arctic regions of oxygenated gasoline containing methyl tertiary
butyl ether ("MTBE") prompted early discontinuance of the program in Fairbanks.
The EPA has been directed to conduct studies of potential health effects of
oxygenated fuel in Alaska. The state of Alaska mandated the use of oxygenated
fuels containing ethanol in the Anchorage area. No requirements for use of such
products in Fairbanks have been issued, but are expected. Additional federal
regulations promulgated on August 21, 1990, which went into effect on October 1,
1993, set limits on the quantity of sulphur in on-highway diesel fuels which the
Company
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<PAGE> 86
produces. The state filed an application with the federal government in February
1993 for a waiver from this requirement since only 5% of the diesel fuel sold in
Alaska was for on-highway vehicles. On March 14, 1994, the EPA granted the State
of Alaska a waiver from the requirements of the EPA's low sulphur diesel fuel
program, permanently exempting Alaska's remote areas and providing a temporary
exemption for areas served by the Federal Aid Highway System until October 1,
1996. On August 19, 1996, the EPA extended the temporary exemption until October
1, 1998. The Company estimates that substantial capital expenditures would be
required to enable the Company to produce low-sulphur diesel fuel to meet these
federal regulations. If the state of Alaska is unable to obtain a permanent
waiver from the federal regulations, the Company would discontinue sales of
diesel fuel for on-highway use after October 1, 1998. The Company estimates that
such sales accounted for less than 1% of its refined product sales in Alaska
during 1997. While the Company is unable to predict the outcome of these
matters, their ultimate resolution should not have a material impact on its
operations.
Underground Storage Tanks. Regulations promulgated by the EPA on September
23, 1988, require that all underground storage tanks used for storing gasoline
or diesel fuels either be closed or upgraded not later than December 22, 1998,
in accordance with specified regulatory standards. The Company's gasoline retail
stations which are subject to upgrading requirements are limited to sites in
Alaska and Hawaii. The Company is expected to incur a total cost of
approximately $1 million by December 22, 1998 for the removal, replacement or
upgrading of underground storage tanks at current and former service stations in
Alaska and Hawaii. In Hawaii, all but two gasoline retail stations have been
brought into compliance with the 1998 regulatory requirements. Of the two
remaining, one station is scheduled to be demolished and completely rebuilt to
comply with regulatory requirements. Pending resolution of a dispute over the
lease to the other station, the Company has not to date scheduled nor committed
to complete upgrades until its interests to the property are resolved. If the
Company commits to remain at the site, then the necessary upgrades will be
completed prior to the regulatory deadline.
Total Environmental Expenditures. Tesoro's total capital expenditures for
environmental control purposes were $2.2 million during 1997. Capital
expenditures for the alternate secondary containment systems in Alaska,
discussed above, are estimated to be $2 million in 1998 and $2 million in 1999
with the remaining $5 million to be spent by 2002. Capital expenditures for
other Alaska environmental control purposes are estimated to be $7 million in
1998 and $2 million in 1999. Capital expenditures for Hawaii environmental
controls are expected to be $4 million in 1998 and $1 million in 1999, the
majority of which are to install specific sulphur emission control devices at
the Hawaii Refinery. Capital expenditures for the Washington Refinery are
expected to be $2 million in 1998 and $1 million in 1999, primarily for new
storage tank roof seals and improving drainage controls. For further information
regarding environmental matters, see "-- Legal Proceedings" and
"-- Environmental Controls," "-- Oil Spill Prevention and Response" and
"-- Underground Storage Tanks."
Oil Spill Prevention and Response. The Federal Oil Pollution Act of 1990
("OPA 90") and related state regulations require most refining, transportation
and oil storage facilities to prepare oil spill prevention contingency plans for
use during an oil spill response. The Company has prepared and submitted these
plans for approval and, in most cases, has received federal and state approvals
necessary to meet various regulations and to avoid the potential of negative
impacts on the operation of its facilities.
The Company currently charters tankers to transport crude oil from the
Valdez, Alaska, pipeline terminal through Prince William Sound and Cook Inlet to
the Alaska Refinery. In addition, the Company routinely charters, on a long-term
and short-term basis, additional tankers and barges for shipment of crude oil
and refined products through Alaska, Pacific Northwest and Hawaii waters. OPA 90
requires, as a condition of operation, that the Company demonstrate the
capability to respond to the "worst case discharge" to the maximum extent
practicable. Alaska law requires the Company to provide spill-response
capability to contain or control, and cleanup within 72 hours, an amount equal
to (i) 50,000 barrels for a tanker carrying fewer than 500,000 barrels of crude
oil or (ii) 300,000 barrels for a tanker carrying more than 500,000 barrels. To
meet these requirements, the Company has entered into a contract with Alyeska
Pipeline Service Company ("Alyeska") to provide initial spill response services
in Prince William Sound, with the Company later to assume those responsibilities
after mutual agreement with Alyeska and State and Federal On-Scene
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<PAGE> 87
Coordinators. The Company has also entered into an agreement with Cook Inlet
Spill Prevention and Response, Incorporated for oil spill response services in
Cook Inlet. Similarly, the Company has entered into contracts with the Clean
Islands Council in Hawaii, Clean Sound Cooperative, Inc. in the State of
Washington and the Marine Spill Response Corporation in Hawaii, Washington and
the Texas-Louisiana Gulf Coast, for spill response services. The Company
believes these contracts provide for the additional services necessary to meet
spill response requirements established by state and federal law.
Transportation, storage and refining of crude oil results in the greatest
regulatory impact with respect to oil spill prevention and response. Oil
transportation and terminalling operations at other Company facilities also
result in compliance mandates for oil spill prevention and response. The Company
contracts with various oil spill response cooperatives or local contractors to
provide necessary oil spill response capabilities which may be required on a
location by location basis.
Regulations promulgated by the Alaska Department of Environmental
Conservation ("ADEC") would have required the installation of dike liners in
secondary containment systems for petroleum storage tanks by January 1997.
However, on December 18, 1996, ADEC approved the Company's alternative
compliance schedule which allows the Company until the year 2002 to implement
alternative secondary containment systems for all of the Company's existing
petroleum storage tank facilities. The total estimated cost of these
improvements is approximately $9 million, which is expected to be spent over a
five-year period beginning in 1998.
BOLIVIA
The Company's operations in Bolivia are subject to the Bolivian
Hydrocarbons Law and various other laws and regulations. In the Company's
opinion, neither the Hydrocarbons Law nor other requirements currently imposed
by Bolivian laws, regulations and practices will have a material adverse effect
upon its Bolivian operations. For information on the Bolivian Hydrocarbons Law
and Bolivian taxation, see " -- Exploration and Production -- Bolivia" discussed
above.
EMPLOYEES
At December 31, 1997, Tesoro employed approximately 1,100 persons, of whom
approximately 40 were located in foreign countries, BHP Hawaii employed
approximately 800 persons and Shell Washington employed approximately 300
persons. Approximately 180 employees at the Washington Refinery are covered by a
collective bargaining agreement. The Company considers its relations with its
employees to be satisfactory.
LEGAL PROCEEDINGS
The Company, along with numerous other parties, has been identified by the
EPA as a potentially responsible party ("PRP") pursuant to the Comprehensive
Environmental Response, Compensation and Liability Act ("CERCLA") for the D.L.
Mud Superfund site in Abbeville, Louisiana (the "Site"). The Company arranged
for the disposal of a minimal amount of materials at the Site, but CERCLA might
impose joint and several liability on each PRP at the Site. The EPA is seeking
reimbursement for its response costs incurred to date at the Site, as well as a
commitment from the PRPs either to conduct future remedial activities or to
finance such activities. The extent of the Company's allocated financial
contributions to the cleanup of the Site is expected to be limited based upon
the number of companies, volumes of waste involved, and an estimated total cost
of approximately $500,000 among all of the parties to close the Site. The
Company is currently involved in settlement discussions with the EPA and other
PRPs involved at the Site. The Company expects, based on these discussions, that
its liability at the Site will not exceed $25,000.
The Hawaii Department of Health ("HDOH"), under authority of the Hawaii
Environmental Response Law, has undertaken an investigation of environmental
conditions within a portion of the Honolulu Harbor area, which has been
designated the Iwilei Unit, to determine the extent of hydrocarbon
contamination. A group of owners and operators at the Iwilei Unit, including BHP
Hawaii, have entered into a voluntary agreement with the HDOH to undertake an
initial phase of environmental site investigation within the Iwilei
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<PAGE> 88
unit in exchange for certain commitments from the HDOH, including the
notification of additional potentially responsible parties to participate in
this activity. The costs associated with this proceeding cannot be determined at
this early stage. BHP Hawaii owned and operated facilities in the Iwilei unit,
including, but not limited to the Pier 29 terminal facilities (which were
returned, upon expiration of the lease term, to the state of Hawaii Department
of Transportation) and the Pier 34 terminal facilities (which are now owned and
operated by the Company under a lease with the same agency). Under the indemnity
provisions of the environmental agreement between the BHP Sellers and the
Company, the Company is fully indemnified for claims arising out of this
proceeding as it relates to the Iwilei Unit by affiliates of BHP and this
indemnity is not subject to the $9.5 million cap or ten-year claim period. See
discussion in "-- Government Regulation and Legislation" above.
The EPA issued a Notice of Violation ("NOV") on June 24, 1997, against the
Hawaii Refinery alleging violations of the Clean Water Act associated with the
content and implementation of the Refinery's Spill Prevention, Control and
Countermeasures ("SPCC") Plan, and further alleging violations based on a series
of oil releases. The Company and the EPA remain engaged in settlement
discussions with remaining issues limited to alleged deficiencies in the content
of the refinery Spill Prevention, Control and Countermeasures Plan. This
proceeding is subject to the indemnity provision of the environmental agreement
between BHP Sellers and the Company.
Also on June 24, 1997, a NOV was issued against BHP Companies pursuant to
Section 103 of CERCLA and Section 304 of the Emergency Planning and Community
Right to Know Act ("EPCRA") regarding past releases of reportable quantities of
regulated substances and oil. This matter remains subject to EPA review and
penalty amounts have not been assessed to date. This proceeding is subject to
the indemnity provisions of the environmental agreement between BHP Sellers and
the Company.
On August 5, 1996, the EPA issued a Finding of Violation ("FOV") against
BHP Hawaii pursuant to disclosures made by BHP Hawaii pursuant to a permit
application for compliance with Title V of the Clean Air Act. The parties have
engaged in settlement negotiations and no penalty amount has been assessed. This
proceeding is subject to the indemnity provision of the environmental agreement
between affiliates of BHP and the Company. See discussion in "-- Government
Regulation and Legislation" above.
The EPA issued a NOV on May 19, 1998, against the Alaska Refinery alleging
violations of the Resource Conservation and Recovery Act ("RCRA") associated
with the failure to maintain closure of certain containers of hazardous waste
when not in use and the failure to retain on-site certain records of land
disposal restriction notifications. The Company has initiated an investigation
into these allegations, but does not believe that the resolution thereof will
have a material effect on the Company.
The EPA has notified Shell that it is a PRP at the Swinomish dump site in
Washington State. In the environmental agreement between Shell Washington and
the Company, Shell has fully indemnified the Company for environmental
liabilities arising from wastes delivered to the Swinomish dump site prior to
the closing of the Washington Acquisition. The Company does not currently plan
to utilize this site following the closing of the Washington Acquisition.
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<PAGE> 89
MANAGEMENT
INFORMATION CONCERNING EXECUTIVE OFFICERS
The following is a list of Tesoro's executive officers, their ages and
their positions with the Company at July 1, 1998.
<TABLE>
<CAPTION>
NAME AGE POSITION POSITION HELD SINCE
- ---- --- -------- -------------------
<S> <C> <C> <C>
Bruce A. Smith.................... 54 Chairman of the Board of June 1996
Directors, President and Chief
Executive Officer
William T. Van Kleef.............. 46 Executive Vice President, September 1996
Operations
James C. Reed, Jr................. 53 Executive Vice President, General September 1995
Counsel and Secretary
Thomas E. Reardon................. 52 Senior Vice President, Corporate May 1998
Resources
Donald A. Nyberg.................. 46 President, Tesoro Marine Services, November 1996
Inc.
Robert W. Oliver.................. 44 President, Tesoro Exploration and September 1995
Production Company
Stephen L. Wormington............. 53 President, Tesoro Alaska Petroleum May 1998
Company, and Executive Vice
President and Chief Operating
Officer of Tesoro Refining,
Marketing & Supply Company
Don E. Beere...................... 57 Vice President, Information May 1998
Technology Projects
Don M. Heep....................... 49 Vice President, Controller May 1998
Gregory A. Wright................. 48 Vice President, Finance and May 1998
Treasurer
</TABLE>
There are no family relationships among the officers listed, and there are
no arrangements or understandings pursuant to which any of them were elected as
officers. Officers are elected annually by the Board of Directors at its first
meeting following the Annual Meeting of Stockholders, each to hold office until
the corresponding meeting of the Board in the next year or until a successor
shall have been elected or shall have qualified.
All of the Company's executive officers have been employed by the Company
or its subsidiaries in an executive capacity for at least the past five years,
except for those named below who have had the business experience indicated
during that period. Positions, unless otherwise specified, are with the Company.
William T. Van Kleef....... Executive Vice President, Operations since
September 1996. Senior Vice President and Chief
Financial Officer from September 1995 to September
1996. Vice President, Treasurer from March 1993 to
September 1995. Independent financial consultant
from January 1992 to February 1993.
Thomas E. Reardon.......... Senior Vice President, Corporate Resources since
May 1998. Vice President, Human Resources and
Environmental, from September 1995 to May 1998.
Vice President, Human Resources and Environmental
Services, of Tesoro Petroleum Companies, Inc., a
subsidiary of the Company, from October 1994 to
September 1995. Vice President, Human Resources, of
Tesoro Petroleum Companies, Inc. from February 1990
to October 1994.
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<PAGE> 90
Donald A. Nyberg........... President of Tesoro Marine Services, Inc., a
subsidiary of the Company, since November 1996.
Vice President, Strategic Planning, of MAPCO Inc.
from January 1996 to November 1996. President and
Chief Executive Officer of Marya Resources from
August 1994 to January 1996. President and Chief
Executive Officer of BP Pipelines Inc. and Vice
President, BP Exploration, of The British Petroleum
Group, Ltd., from 1991 to 1994.
Robert W. Oliver........... President of Tesoro Exploration and Production
Company, a subsidiary of the Company, since
September 1995. Independent consultant from
November 1994 to September 1995. Vice President,
Exploration/Acquisitions, of Bridge Oil (USA) Inc.
from December 1988 to November 1994.
Stephen L. Wormington...... President of Tesoro Alaska Petroleum Company, a
subsidiary of the Company, since September 1995,
and Executive Vice President and Chief Operating
Officer of Tesoro Refining, Marketing & Supply
Company, a subsidiary of the Company, since May
1998. Vice President, Supply and Operations
Coordination, of Tesoro Alaska Petroleum Company
from April 1995 to September 1995. General Manager,
Strategic Projects, from January 1995 to April
1995. Executive Vice President, Special Projects,
of MG Refining & Marketing, Inc. from January 1994
to January 1995. Executive Vice President of MG
Natural Gas Corp. from May 1992 to January 1994.
Don M. Heep................ Vice President, Controller since May 1998. Senior
Vice President, Administration for Tesoro Alaska
Petroleum Company, a subsidiary of the Company,
from November 1996 to May 1998. Senior Vice
President and Chief Financial Officer of Valero
Energy Corporation from 1994 to 1996. Vice
President and Chief Accounting Officer of Valero
Energy Corporation from 1992 to 1994.
Gregory A. Wright.......... Vice President, Finance and Treasurer since May
1998. Vice President and Treasurer from September
1995 until May 1998. Vice President, Corporate
Communications, from February 1995 to September
1995. Vice President, Corporate Communications, of
Tesoro Petroleum Companies, Inc., a subsidiary of
the Company, from January 1995 to February 1995.
Vice President, Business Development, of Valero
Energy Corporation from 1994 to January 1995. Vice
President, Corporate Planning, of Valero Energy
Corporation from 1992 to 1994.
INFORMATION CONCERNING DIRECTORS
Certain information as to each director is set forth in the table below and
in the following paragraphs. Certain of the information appearing in the table
and the notes thereto has been furnished to the Company by the respective
directors.
<TABLE>
<CAPTION>
SERVED AS
DIRECTOR OF
AGE AT THE COMPANY
JULY 1, OR PREDECESSOR OTHER POSITIONS AND OFFICES
NAME 1998 COMPANIES FROM WITH THE COMPANY
---- ------- -------------- ---------------------------
<S> <C> <C> <C>
Steven H. Grapstein................ 40 1992 Vice Chairman of the Board of
Directors(a)(b)(c)
William J. Johnson................. 63 1996 (b)(d)
Alan J. Kaufman.................... 60 1996 (b)(d)
</TABLE>
(Table continued on next page)
87
<PAGE> 91
(Table continued from previous page)
<TABLE>
<CAPTION>
SERVED AS
DIRECTOR OF
AGE AT THE COMPANY
JULY 1, OR PREDECESSOR OTHER POSITIONS AND OFFICES
NAME 1998 COMPANIES FROM WITH THE COMPANY
---- ------- -------------- ---------------------------
<S> <C> <C> <C>
Raymond K. Mason, Sr............... 71 1983 (a)(d)
Bruce A. Smith..................... 54 1995 Chairman of the Board of Directors,
President and Chief Executive
Officer(a)
Patrick J. Ward.................... 67 1996 (c)(d)
Murray L. Weidenbaum............... 71 1992 (a)(c)
</TABLE>
- ---------------
(a) Member of the Executive Committee (Mr. Smith, Chairman).
(b) Member of the Audit Committee (Mr. Grapstein, Chairman).
(c) Member of the Governance Committee (Dr. Weidenbaum, Chairman).
(d) Member of the Compensation Committee (Mr. Mason, Chairman).
Steven H. Grapstein has been Chief Executive Officer of Kuo Investment
Company and subsidiaries ("Kuo"), an international investment group, since
January 1997. From September 1985 to January 1997, Mr. Grapstein was a Vice
President of Kuo. He is also a director of several of the Kuo companies. Mr.
Grapstein has been a Vice President of Oakville N.V. since 1989. Mr. Grapstein
is also a director of Baldwin Plc., which is an entertainment and
leisure-related entity.
William J. Johnson has been a petroleum consultant and investor since 1994.
From 1990 through 1994, Mr. Johnson served as President, Chief Operating Officer
and a director of Apache Corporation, a large independent oil and gas company.
Mr. Johnson is on the Board of Directors of Camco International, Inc., an oil
field equipment and services company; Snyder Oil Corporation, an exploration and
production company; and J. Ray McDermott, S.A., an engineering and construction
company.
Alan J. Kaufman, M.D., is an investor in a number of companies and a
retired neurosurgeon. Since 1987, he has been a director of Newpark Resources,
Inc., a company engaged primarily in providing oil field services.
Raymond K. Mason, Sr., has been Chairman of the Board of Directors of
American Banks of Florida, Inc. since 1978.
Bruce A. Smith has been Chairman of the Board of Directors, President and
Chief Executive Officer of the Company since June 1996. He has been a director
of the Company since July 1995. Mr. Smith was President and Chief Executive
Officer of the Company from September 1995 to June 1996; Executive Vice
President, Chief Financial Officer and Chief Operating Officer of the Company
from July 1995 to September 1995; Executive Vice President responsible for
Exploration and Production and Chief Financial Officer of the Company from
September 1993 to July 1995; and Vice President and Chief Financial Officer of
the Company from September 1992 to September 1993.
Patrick J. Ward has 47 years of experience in international energy
operations with Caltex Petroleum Corporation, a 50/50 joint venture of Chevron
Corp. and Texaco, Inc., engaged in the business of refining and marketing. Prior
to his retirement in August 1995, he was Chairman, President and Chief Executive
Officer of Caltex, positions he held since 1990.
Murray L. Weidenbaum, an economist and educator, has been the Mallinckrodt
Distinguished University Professor and Chairman of the Center for the Study of
American Business at Washington University in St. Louis, Missouri, since 1975.
Dr. Weidenbaum is a director of May Department Stores Company.
No director of the Company has a family relationship with any other
director or executive officer of the Company.
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<PAGE> 92
DESCRIPTION OF OTHER INDEBTEDNESS
In conjunction with the closing of the Hawaii Acquisition, Tesoro
refinanced substantially all of its existing indebtedness. The total amount of
funds required by Tesoro to complete the Hawaii Acquisition and the Refinancing,
to pay related fees and expenses and for general corporate purposes was
approximately $432 million, which was financed through the Interim Credit
Facility provided by LCPI. All borrowings under the Interim Credit Facility were
refinanced with net proceeds from the Offerings and borrowings under the Senior
Credit Facility described below.
SENIOR CREDIT FACILITY
On July 2, 1998, the Interim Credit Facility was amended and restated as
the Senior Credit Facility. The following is a summary of the material terms and
conditions of the Senior Credit Facility and the various related documents
entered into a connection therewith.
Loans, Interest Rates. The Senior Credit Facility is comprised of term loan
facilities aggregating not more than $200 million of Term Loans and a $300
million Revolver, which was implemented in conjunction with the closing of the
Offerings. The Term Loans consist of Tranche A Term Loans ($50 million of which
was initially funded) and a $100 million Tranche B Term Loan. In addition, the
Company may borrow up to $50 million under the Tranche A Term Loans, in up to
five draws, for a period of up to six months following the closing of the Senior
Credit Facility. The Revolver is available on a revolving basis during the
period commencing on the date of the closing of the Senior Credit Facility and
ending on the date that is three years after the date of the closing of the
Senior Credit Facility. The Revolver and the Tranche A Term Loans will bear
interest, at the Company's election, at either the Base Rate (as defined in the
Senior Credit Facility) plus a margin ranging from 0.00% to 0.625% or the
Eurodollar Rate (as defined in the Senior Credit Facility) plus a margin ranging
from 1.125% to 2.125%. The Tranche B Term Loan will bear interest, at the
Company's election, at either the Base Rate plus a margin ranging from 0.50% to
0.625% or the Eurodollar Rate plus a margin ranging from 2.00% to 2.125%.
Repayment. The principal amount of the Tranche A Loans and the Tranche B
Loan is repayable in quarterly installments during their respective terms in the
following approximate aggregate annual amounts:
<TABLE>
<CAPTION>
TRANCHE A LOANS(a) TRANCHE B LOAN
- ------------------------------------- -------------------------------------
YEAR AMOUNT YEAR AMOUNT
---- ----------- ---- -----------
<S> <C> <C> <C>
1...................... $ 0 1...................... $ 1,000,000
2...................... 20,000,000 2...................... 1,000,000
3...................... 25,000,000 3...................... 1,000,000
4...................... 25,000,000 4...................... 1,000,000
5...................... 30,000,000 5...................... 1,000,000
5 1/2.................. 95,000,000
</TABLE>
- ---------------
(a) Assuming the $50 million of additional borrowing capacity under the Tranche
A Term Loans is fully utilized.
Security. The obligations under the Senior Credit Facility and the related
documents are secured by a first priority lien upon all material domestic real
and personal property of the Company and its subsidiaries, including its
refineries and domestic oil and gas reserves, and a pledge of all of the capital
stock of the Company's active subsidiaries (provided that no lien has been
granted on the assets of foreign subsidiaries and no capital stock of foreign
subsidiaries has been pledged to the extent that the granting of such lien or
the making of such pledge would result in materially adverse United States
Federal income tax consequences to the Company or would violate applicable law).
Guarantees. The obligations of the Company under the Senior Credit Facility
are guaranteed by all of the Company's active subsidiaries (provided that no
guarantee by a foreign subsidiary has been made if such guarantee would result
in materially adverse United States federal income tax consequences to the
Company or would violate applicable law).
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<PAGE> 93
Prepayment. The Company is required to make prepayments to the Tranche A
Term Loans and Tranche B Term Loan, with customary exceptions, in an amount
equal to 100% of the net proceeds of certain incurred indebtedness, 100% of the
net proceeds received by the Company and its subsidiaries (other than certain
net proceeds reinvested in the business of the Company or its subsidiaries) from
the disposition of any assets, including proceeds from the sale of stock of any
of the Company's subsidiaries and a percentage of excess cash flow, depending on
certain credit statistics.
Conditions and Covenants. The obligations of the lenders under the Senior
Credit Facility are subject to the satisfaction of certain conditions precedent
customary in similar credit facilities or otherwise appropriate under the
circumstances. The Company and each of its subsidiaries is subject to certain
negative covenants contained in the Senior Credit Facility, including, without
limitation, covenants that restrict, subject to specified exceptions: (i) the
incurrence of additional indebtedness and other obligations and the granting of
additional liens; (ii) mergers, acquisitions, investments and acquisitions and
dispositions of assets; (iii) investments, loans and advances; (iv) dividends,
stock repurchases and redemptions; (v) prepayment or repurchase of other
indebtedness and amendments to certain agreements governing indebtedness,
including the Indenture and the Notes; (vi) engaging in transactions with
affiliates; (vii) sales and leasebacks; (viii) changes in fiscal periods; (ix)
changes of lines of business; and (x) entering into agreements which prohibit
the creation of liens or limit the Company's subsidiaries' ability to pay
dividends. The Senior Credit Facility also contains customary affirmative
covenants, including compliance with environmental laws, maintenance of
corporate existence and rights, maintenance of insurance, property and interest
rate protection, financial reporting, inspection of property, books and records
and agreements to cause Shell Washington and its subsidiaries, if any, to become
Guarantors and to create security interests in their assets. In addition, the
Senior Credit Facility requires the Company to maintain compliance with certain
specified financial covenants including a maximum ratio of total debt to EBITDA
and a minimum interest coverage ratio. Certain of these financial, negative and
affirmative covenants are more restrictive than those set forth in the
Indenture.
Events of Default. The Senior Credit Facility also includes events of
default that are typical for senior credit facilities and appropriate in the
context of the Transactions, including, without limitation, nonpayment of
principal, interest, fees or reimbursement obligations with respect to letters
of credit, violation of covenants, inaccuracy of representations and warranties
in any material respect, cross default to certain other indebtedness and
agreements, bankruptcy and insolvency events, material judgments and
liabilities, defaults or judgments under ERISA and change of control. The
occurrence of any of such events of default could result in acceleration of the
Company's obligations under the Senior Credit Facility and foreclosure on the
collateral securing such obligations, which could have material adverse results
to holders of the Notes.
Failure to Close Washington Acquisition. In the event that the Washington
Acquisition does not close on or prior to December 31, 1998, the difference
between the amount of proceeds used to fund the Special Redemption ($151.5
million) and the amount held in escrow for the Washington Acquisition ($266.9
million) will be used first to prepay the Tranche B Term Loan with any remainder
to prepay outstanding Tranche A Term Loans. Simultaneously with such prepayment,
(i) the Revolver will be reduced to $250 million, (ii) the portion of the
Revolver available for letters of credit will be reduced to $150 million and
(iii) the undrawn commitments under the Tranche A Term Loans will be reduced by
an amount equal to the outstanding principal amount of the Tranche A Term Loans
after giving effect to the foregoing prepayment.
OTHER INDEBTEDNESS
After consummation of the Transactions, the Company will have other
indebtedness outstanding consisting primarily of an obligation to the Department
of Energy ("DOE"). See Note I to Tesoro's Consolidated Financial Statements. At
December 31, 1997, the Company's remaining obligation was to pay the DOE $9.2
million, exclusive of interest at 6%, over the next five years. In February
1998, the Company paid the DOE $1.3 million of this amount. The remaining amount
of outstanding indebtedness consists primarily of obligations of subsidiaries
for various equipment and properties, none of which is material to the
consolidated indebtedness of the Company. The Company also has capitalized lease
obligations of approximately $9 million for tugs and barges used in
transportation of petroleum products within Hawaii.
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<PAGE> 94
In connection with the Hawaii Acquisition, the Company issued the BHP Note,
an unsecured, non-interest bearing promissory note in the amount of $50 million
payable in five equal annual installments of $10 million each beginning in May
2009. The BHP Note provides for earlier payment to the extent of one-half of the
amount by which earnings from the acquired assets, before interest expense,
income taxes and depreciation, depletion and amortization, as specified in the
BHP Note, exceed $50 million in any calendar year. Upon acceleration due to an
event of default, the amount outstanding to be paid under the BHP Note will be
reduced to present value using a discount rate of 9%.
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DESCRIPTION OF THE NOTES
GENERAL
The Exchange Notes will be issued, and the Old Notes were issued, pursuant
to an Indenture (the "Indenture") among the Company, the Guarantors and the
Exchange Agent, U.S. Bank Trust National Association, as trustee (the
"Trustee"). The terms of the Notes include those stated in the Indenture and
those made part of the Indenture by reference to the Trust Indenture Act of 1939
(the "Trust Indenture Act"). The Notes are subject to all such terms, and
Holders of Notes are referred to the Indenture and the Trust Indenture Act for a
statement thereof. The following summary of the provisions of the Indenture does
not purport to be complete and is qualified in its entirety by reference to the
Indenture, including the definitions therein of certain terms used below. Copies
of the Indenture and Registration Rights Agreement are available as set forth
below under "-- Additional Information." The definitions of certain terms used
in the following summary are set forth below under "-- Certain Definitions." For
purposes of this summary, the term "Company" refers only to Tesoro Petroleum
Corporation and not to any of its Subsidiaries.
The Exchange Notes will be issued in increments of $1,000 solely in
exchange for an equal principal amount of Old Notes pursuant to the Exchange
Offer. The form and terms of the Exchange Notes will be identical in all
material respects to the form and terms of the Old Notes except that the
offering of the Exchange Notes has been registered under the Securities Act, and
the Exchange Notes will therefore not be subject to transfer restrictions,
registration rights and certain provisions relating to the payment of Liquidated
Damages under certain circumstances. See "-- Registration Rights; Liquidated
Damages." The Notes are subject to the terms stated in the Indenture, a copy of
which has been filed as an exhibit to the Registration Statement, and holders of
the Notes are referred thereto for a statement of those terms.
The Old Notes and the Exchange Notes will constitute a single series of
debt securities under the Indenture. If the Exchange Offer is consummated,
holders of Old Notes who do not exchange their Old Notes for Exchange Notes will
vote together with holders of the Exchange Notes for all relevant purposes under
the Indenture. In that regard, the Indenture requires that certain actions by
the holders thereunder (including following an Event of Default) must be taken,
and certain rights must be exercised, by specified minimum percentages of the
aggregate principal amount of the outstanding Notes issued under the Indenture.
In determining whether holders of the requisite percentage in principal amount
have given any notice, consent or waiver or taken any other action permitted
under the Indenture, any Old Notes that remain outstanding after the Exchange
Offer will be aggregated with the Exchange Notes, and the holders of such Old
Notes and the Exchange Notes will vote together as a single class for all such
purposes. Accordingly, all references herein to specified percentages in
aggregate principal amount of the outstanding Notes shall be deemed to mean, at
any time after the Exchange Offer is consummated, such percentages in aggregate
principal amount of the Old Notes and the Exchange Notes then outstanding.
The Notes will be general unsecured obligations of the Company and will be
subordinated in right of payment to all current and future Senior Debt of the
Company, including borrowings under the Senior Credit Facility. All Indebtedness
incurred by the Company under the Senior Credit Facility will be secured by
substantially all of the Company's domestic assets and the Capital Stock of all
of the Company's existing and future active Subsidiaries (other than a minority
interest in foreign Subsidiaries), and will be guaranteed by substantially all
of the active Subsidiaries, which guarantees will be secured by substantially
all of such Subsidiaries' assets. The Notes will be guaranteed by all of the
Company's existing and future Subsidiaries that guarantee any Indebtedness of
the Company. The Notes will rank pari passu in right of payment with all other
senior subordinated Indebtedness of the Company issued in the future, if any,
and senior in the right of payment to all other subordinated Indebtedness of the
Company issued in the future, if any. As of March 31, 1998, on a pro forma basis
giving effect to the Transactions, the Company and its Subsidiaries would have
had approximately $185.2 million of Senior Debt outstanding (exclusive of an
additional approximately $350.0 million available under the Senior Credit
Facility, which if drawn would also be Senior Debt). The Indenture limits,
subject to certain financial tests and exceptions, the amount of additional
Indebtedness, including Senior Debt, that the Company and its Restricted
Subsidiaries may incur. See "-- Certain Covenants -- Incurrence of Indebtedness
and Issuance of Preferred Stock."
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As of the Issue Date, all of the Company's Subsidiaries will be Restricted
Subsidiaries. Under certain circumstances, the Company will be able to designate
current or future Subsidiaries as Unrestricted Subsidiaries. Unrestricted
Subsidiaries will not be subject to any of the restrictive covenants set forth
in the Indenture. See "-- Certain Covenants -- Restricted Payments."
PRINCIPAL, MATURITY AND INTEREST
The Notes will be limited in aggregate principal amount to $350 million,
$300 million of which were issued in the Notes Offering, and mature on July 1,
2008. Additional amounts may be issued after the Issue Date in one or more
series from time to time subject to the limitations set forth under the caption
"-- Certain Covenants -- Incurrence of Indebtedness and Issuance of Preferred
Stock" and restrictions contained in the Senior Credit Facility and any other
agreement to which the Company is a party at the time of such issuance. The
Company has agreed not to offer, issue or sell any notes, bonds or other amounts
under the Indenture other than the Notes for a period of 180 days from the Issue
Date without the prior written consent of Lehman Brothers. Interest on the Notes
will accrue at the rate of 9% per annum and will be payable semi-annually in
arrears on January 1 and July 1, commencing on January 1, 1999, to Holders of
record on the immediately preceding December 15 and June 15. Interest on the
Notes will accrue from the most recent date to which interest and Liquidated
Damages, if any, has been paid or, if no interest has been paid, from the date
of original issuance. Interest will be computed on the basis of a 360-day year
comprised of twelve 30-day months. Principal of, and, premium, if any, and
interest and Liquidated Damages, if any, on, the Notes will be payable at the
office or agency of the Company maintained for such purpose within the City and
State of New York or, at the option of the Company, payment of interest and
Liquidated Damages, if any, may be made by check mailed to the Holders of the
Notes at their respective addresses set forth in the register of Holders of
Notes; provided that all payments with respect to Notes the Holders of which
have given wire transfer instructions to the Company will be required to be made
by wire transfer of immediately available funds to the accounts specified by the
Holders thereof. Until otherwise designated by the Company, the Company's office
or agency in New York will be the office of the Trustee maintained for such
purpose. The Notes will be issued in denominations of $1,000 and integral
multiples thereof.
SUBORDINATION
The payment of principal of, and premium, if any, and interest and
Liquidated Damages, if any, on the Notes is subordinated in right of payment, as
set forth in the Indenture, to the prior payment in full, in cash, of all Senior
Debt of the Company, whether outstanding on the Issue Date or thereafter
incurred, assumed or guaranteed.
Upon any distribution to creditors of the Company in a liquidation or
dissolution of the Company or in a bankruptcy, reorganization, insolvency,
receivership or similar proceeding relating to the Company or its property, in
an assignment for the benefit of creditors or any marshaling of the Company's
assets and liabilities, the holders of Senior Debt of the Company will be
entitled to receive payment in full, in cash, of all Obligations due in respect
of such Senior Debt (including interest after the commencement of any such
proceeding at the rate specified in the applicable Senior Debt (whether or not
an allowable claim)) before the Holders of Notes will be entitled to receive any
payment with respect to the Notes, and until all Obligations with respect to
such Senior Debt are paid in full, in cash, pursuant to such liquidation or
dissolution, any such distribution to which the Holders of Notes would be
entitled shall be made to the holders of such Senior Debt (except that Holders
of Notes may receive and retain (i) Permitted Junior Securities, (ii) payments
made from the trust described under "-- Legal Defeasance and Covenant
Defeasance" or "-- Satisfaction and Discharge"; provided that at the time of its
creation such trust does not violate the Senior Credit Facility and (iii)
payments from funds released to the Company or the Trustee from escrow under the
Washington Agreement for payment of the Special Redemption Price as described
under "-- Special Redemption.")
The Company also may not make any payment upon or in respect of the Notes
(except (i) in Permitted Junior Securities, (ii) from the trust described under
"-- Legal Defeasance and Covenant Defeasance" or "-- Satisfaction and
Discharge"; provided that at the time of its creation such trust does not
violate the Senior Credit Facility or (iii) payments from funds released to the
Company or the Trustee from escrow under the Washington Agreement for payment of
the Special Redemption Price as described under "-- Special
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Redemption") if (i) a default in the payment, when due, of the principal of, or
premium, if any, or interest on, Designated Senior Debt occurs and is continuing
beyond any applicable period of grace (a "Payment Default") or (ii) any other
default occurs and is continuing with respect to Designated Senior Debt that
permits holders of the Designated Senior Debt as to which such default relates
to accelerate its maturity without further notice or the expiration of any
applicable grace periods (a "Nonpayment Default") and the Trustee receives (and
the Company receives, if not sent by the Company) a notice of such default (a
"Payment Blockage Notice") from the Representative of the holders of any
Designated Senior Debt specifying an election to effect a payment blockage for
the period specified in the next sentence. Payments on the Notes may and shall
be resumed (a) in the case of a Payment Default, upon the date on which such
default is cured or waived or any acceleration is rescinded, as applicable and
(b) in case of a Nonpayment Default, the earlier of the date on which such
Nonpayment Default is cured or waived or 179 days after the date on which the
applicable Payment Blockage Notice is received, unless the maturity of any
Designated Senior Debt has been accelerated and not thereafter rescinded,
provided, in each case, the Company may pay the Notes without regard to the
foregoing if it and the Trustee receive written notice approving same from
Representatives of each Designated Senior Debt. No new period of payment
blockage may be commenced unless and until (i) 360 days have elapsed since the
effectiveness of the immediately prior Payment Blockage Notice and (ii) all
scheduled payments of principal of, and, premium, if any, and interest and
Liquidated Damages, if any, on, the Notes that have come due have been paid in
full in cash. No Nonpayment Default that existed or was continuing on the date
of delivery of any Payment Blockage Notice to the Trustee shall be, or be made,
the basis for a subsequent Payment Blockage Notice unless such default shall
have been cured or waived for a period of not less than 90 days.
The Indenture further requires that the Company promptly notify holders of
Senior Debt if payment of the Notes is accelerated because of an Event of
Default.
As a result of the subordination provisions described above, in the event
of a liquidation or insolvency, Holders of Notes may recover less ratably than
creditors of the Company who are holders of its Senior Debt or holders of debt
of the Company which is pari passu with the Notes but not expressly subordinated
to such Senior Debt. On a pro forma basis, after giving effect to the
Transactions, the Company and the Guarantors would have had approximately $185.2
million of Senior Debt outstanding at March 31, 1998 (exclusive of an additional
$350.0 million available under the Senior Credit Facility, which, if drawn,
would be Senior Debt). The Indenture limits, subject to certain financial tests,
the amount of additional Indebtedness, including Senior Debt, that the Company
and its Restricted Subsidiaries can incur. See "-- Certain Covenants --
Incurrence of Indebtedness and Issuance of Preferred Stock."
SUBSIDIARY GUARANTEES
The Company's payment obligations under the Notes are jointly and severally
guaranteed on a senior subordinated basis by the Guarantors. Any Subsidiary of
the Company that guarantees any Indebtedness of the Company shall be required to
execute Subsidiary Guarantees and become a Guarantor under the Indenture. The
Subsidiary Guarantee of each Guarantor is subordinated to the prior payment in
full of all Senior Debt of such Guarantor, and the amounts for which the
Guarantors are liable under its guarantees issued from time to time with respect
to Senior Debt of the Company, in each case to the same extent as the
Obligations of the Company with respect to the Notes are subordinated to Senior
Debt of the Company. An aggregate amount of $12.7 million of Senior Debt of all
Guarantors (excluding guarantees of Senior Debt of the Company) was outstanding
on a pro forma basis after giving effect to the Transactions as of March 31,
1998. The obligations of each Guarantor under its Subsidiary Guarantee are
limited to the maximum amount the Guarantors are permitted to guarantee under
applicable law without creating a "fraudulent conveyance." See "Risk
Factors -- Fraudulent Conveyance Considerations Relating to Subsidiary
Guarantees."
The Indenture provides that, subject to the provisions of the following
paragraph, no Guarantor may consolidate with or merge with or into (whether or
not such Guarantor is the surviving Person), another Person whether or not
affiliated with such Guarantor unless (i) the Person formed by or surviving any
such consolidation or merger (if other than such Guarantor) assumes all the
obligations of such Guarantor pursuant to a supplemental indenture in form and
substance reasonably satisfactory to the Trustee, under the
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Notes and the Indenture; (ii) immediately after giving effect to such
transaction, no Default or Event of Default exists; (iii) such Guarantor, or any
Person formed by or surviving any such consolidation or merger, would have
Consolidated Net Worth (immediately after giving effect to such transaction)
equal to or greater than the Consolidated Net Worth of such Guarantor
immediately preceding the transaction; and (iv) the Company would be permitted
by virtue of the Company's pro forma Fixed Charge Coverage Ratio, immediately
after giving effect to such transaction, to incur at least $1.00 of additional
Indebtedness pursuant to the Fixed Charge Coverage Ratio test set forth in the
covenant described above under the caption "-- Certain Covenants -- Incurrence
of Indebtedness and Issuance of Preferred Stock."
Notwithstanding the foregoing paragraph, (i) any Guarantor may consolidate
with, merge into or transfer all or a part of its properties and assets to the
Company or any other Guarantor, (ii) any Guarantor may consolidate with, merge
into or transfer all or a part of its properties and assets to a Wholly Owned
Restricted Subsidiary of the Company that has no significant assets or
liabilities and was incorporated, organized or formed solely for purpose of
reincorporating or otherwise reorganizing such Guarantor in another State of the
United States; provided that such successor, resultant or transferee Person
continues to be a Guarantor and (iii) the Indenture provides that in certain
circumstances involving the disposition (including by way of merger,
consolidation or otherwise) of all or substantially all assets or all Capital
Stock of any Guarantor, and subject to related conditions, such transaction may
be so consummated and such Guarantor will be released from its Subsidiary
Guarantee and any resultant, surviving or transferee Person shall not be
required to assume such obligations upon the conditions described under the
caption "-- Certain Covenants -- Additional Subsidiary Guarantees."
OPTIONAL REDEMPTION
The Notes will not be redeemable at the Company's option prior to July 1,
2003. Thereafter, the Notes will be subject to redemption at any time or from
time to time at the option of the Company, in whole or in part, upon not less
than 30 nor more than 60 days' notice, at the redemption prices (expressed as
percentages of principal amount) set forth below plus accrued and unpaid
interest and Liquidated Damages, if any, thereon to the applicable redemption
date, if redeemed during the twelve-month period beginning on July 1, of the
years indicated below:
<TABLE>
<CAPTION>
YEAR PERCENTAGE
---- ----------
<S> <C>
2003................................................... 104.5%
2004................................................... 103.0
2005................................................... 101.5
2006 and thereafter.................................... 100.0
</TABLE>
Notwithstanding the foregoing, at any time or from time to time on or
before July 1, 2001, the Company may on any one or more occasions redeem up to
35% of the aggregate principal amount of Notes outstanding at a redemption price
of 109% of the principal amount thereof, plus accrued and unpaid interest, if
any, and Liquidated Damages, if any, thereon, to the redemption date, with the
net cash proceeds of any one or more Public Equity Offerings; provided that at
least 65% of the aggregate principal amount of Notes outstanding on the Issue
Date remains outstanding immediately after each occurrence of such redemption;
and provided, further, that each such redemption shall occur within 90 days of
the date of the closing of such Public Equity Offering.
SELECTION AND NOTICE
If less than all of the Notes are to be redeemed at any time, selection of
Notes for redemption will be made by the Trustee in compliance with the
requirements of the principal national securities exchange, if any, on which the
Notes are listed, or, if the Notes are not so listed, on a pro rata basis, by
lot or by such method as the Trustee shall deem fair and appropriate; provided
that no Notes of $1,000 or less shall be redeemed in part. Notices of
redemption, other than a redemption described under the caption "Special
Redemption," shall be mailed by first class mail at least 30 but not more than
60 days before the redemption date to each Holder of Notes to be redeemed at its
registered address. Notices of redemption may not be conditional. If any Note is
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to be redeemed in part only, the notice of redemption that relates to such Note
shall state the portion of the principal amount thereof to be redeemed. A new
Note in principal amount equal to the unredeemed portion thereof will be issued
in the name of the Holder thereof upon cancellation of the original Note. Notes
called for redemption become due on the date fixed for redemption. On and after
the redemption date, interest and Liquidated Damages, if any, cease to accrue on
Notes or portions of them called for redemption.
SPECIAL REDEMPTION
A portion of the Notes are subject to mandatory redemption if the
Washington Acquisition is not consummated by the Company, or the Washington
Agreement is terminated without consummation of the Washington Acquisition, on
or prior to December 31, 1998. In such event, the Company will be required to
redeem 50% of the aggregate principal amount of the Notes offered hereby (i.e.,
$150 million aggregate principal amount) at a redemption price equal to 101% of
the redeemed principal amount thereof (the "Special Redemption Price"), plus
accrued interest and Liquidated Damages, if any, to the date of redemption. The
date for such redemption (the "Special Redemption Date") is the earlier of
December 31, 1998 and ten business days following the date of termination of the
Washington Agreement without consummation of the Washington Acquisition.
Selection of Notes for special redemption will be made by the Trustee in
compliance with the requirements of the principal national securities exchange,
if any, on which the Notes are listed, or, if the Notes are not so listed, on a
pro rata basis, by lot or by such method as the Trustee shall deem fair and
appropriate; provided that no Notes of $1,000 or less shall be redeemed in part.
Pursuant to the Washington Agreement, the Company deposited into an escrow
account established by agreement with the seller and the Company $266.9 million
to be paid in respect of the Washington Acquisition. The escrow account was
established and funded contemporaneously with the issuance, authentication and
delivery of the Old Notes. The Indenture required the Company to deposit net
proceeds received by the Company from the offer and sale of the Old Notes and,
if additional funds become necessary, from other available cash or borrowings,
in an amount required to be deposited into escrow under the Washington
Agreement. The Company granted a security interest in its interest in the
Washington Acquisition escrow agreement to the Trustee to secure payment of the
Special Redemption Price. The Company also granted a security interest in favor
of the lenders under the Senior Credit Facility to secure the Senior Credit
Facility in respect of any escrow proceeds in excess of the aggregate Special
Redemption Price. The escrow arrangement provides that, in the event the
Washington Acquisition is not consummated prior to December 31, 1998 (or an
earlier date agreed to by the Company and the seller), or the Washington
Agreement is terminated prior to such date without such consummation (without
fault of the Company), the funds held in escrow will be released to the Company
together with any interest or investment proceeds earned thereon. To the extent
funds are released from escrow without consummation of the Washington Agreement,
an amount equal to the aggregate Special Redemption Price will be paid to the
Trustee for payment of the Special Redemption Price in partial redemption of the
Notes as described above. The remainder of funds released from escrow will be
applied to prepay amounts outstanding under the Senior Credit Facility.
The Indenture provides that the Trustee and the Holders of Notes will cease
to have any interest in the Washington Acquisition escrow agreement, or the
right to receive released funds thereunder, upon the delivery of an Officer's
Certificate to the Trustee certifying to the effect that the Washington
Acquisition has been consummated by the Company prior to December 31, 1998. The
escrow arrangements with the seller in the Washington Acquisition permit the
investment of escrowed funds in certain Cash Equivalents having a maturity no
later than the Special Redemption Date and otherwise in accordance with
applicable law as directed by the Company and any investment proceeds thereon
will be available to the Company upon release of the escrow.
MANDATORY REDEMPTION
Except as set forth above under "-- Special Redemption" or below under
"-- Repurchase at the Option of Holders," the Company is not required to make
mandatory redemption or sinking fund payments with respect to the Notes.
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REPURCHASE AT THE OPTION OF HOLDERS
Change of Control. Upon the occurrence of a Change of Control, each Holder
of Notes will have the right to require the Company to repurchase all or any
part (equal to $1,000 or an integral multiple thereof) of such Holder's Notes
pursuant to the offer described below (the "Change of Control Offer") at an
offer price in cash equal to 101% of the aggregate principal amount thereof plus
accrued and unpaid interest and Liquidated Damages, if any, thereon, to the date
of purchase (the "Change of Control Payment"). Within 30 days following any
Change of Control, the Company will mail a notice to each Holder describing the
transaction or transactions that constitute the Change of Control and offering
to repurchase Notes on the date specified in such notice, which date shall be no
earlier than 30 days and no later than 60 days from the date such notice is
mailed (the "Change of Control Payment Date"), pursuant to the procedures
required by the Indenture and described in such notice. The Company will comply
with the requirements of Rule 14e-1 under the Exchange Act and any other
securities laws and regulations thereunder to the extent such laws and
regulations are applicable in connection with the repurchase of the Notes as a
result of a Change of Control.
On the Change of Control Payment Date, the Company will, to the extent
lawful, (i) accept for payment all Notes or portions thereof properly tendered
pursuant to the Change of Control Offer, (ii) deposit with the Paying Agent an
amount equal to the Change of Control Payment in respect of all Notes or
portions thereof so tendered and (iii) deliver or cause to be delivered to the
Trustee the Notes so accepted together with an Officers' Certificate stating the
aggregate principal amount of Notes or portions thereof being purchased by the
Company. The Paying Agent will promptly mail to each Holder of Notes so tendered
the Change of Control Payment for such Notes, and the Trustee will promptly
authenticate and mail (or cause to be transferred by book entry) to each Holder
a new Note equal in principal amount to any unpurchased portion of the Notes
surrendered, if any; provided that each such new Note will be in a principal
amount of $1,000 or an integral multiple thereof. The Indenture provides that,
prior to complying with the provisions of this covenant, but in any event within
90 days following a Change of Control, the Company will either repay all of its
outstanding Senior Debt or obtain the requisite consents, if any, under all
agreements governing such outstanding Senior Debt to permit the repurchase of
Notes required by this covenant. The Company will publicly announce the results
of the Change of Control Offer on or as soon as practicable after the Change of
Control Payment Date.
The Change of Control provisions described above will be applicable whether
or not any other provisions of the Indenture are applicable, except as set forth
under the captions "-- Legal Defeasance and Covenant Defeasance" and
"-- Satisfaction and Discharge." Except as described above with respect to a
Change of Control, the Indenture does not contain provisions that permit the
Holders of the Notes to require that the Company repurchase or redeem the Notes
in the event of a takeover, recapitalization or similar transaction. The
definition of Change of Control includes a phrase relating to the sale, lease,
transfer, conveyance or other disposition of "all or substantially all" of the
assets of the Company. There is little case law interpreting the phrase "all or
substantially all" in the context of an indenture. Because there is no precise
established definition of this phrase, the ability of a holder of Notes to
require the Company to repurchase such Notes as a result of a sale, lease,
exchange or other transfer of all or substantially all of the Company's assets
to a Person or a Group may be uncertain.
The Senior Credit Facility limits the ability of the Company to purchase
any Notes and also provides that certain change of control events with respect
to the Company constitute a default thereunder. Any future Credit Facilities or
other agreements relating to Senior Debt to which the Company becomes a party
may contain similar restrictions and provisions. In the event a Change of
Control occurs at a time when the Company is prohibited from purchasing Notes,
the Company could seek the consent of its lenders to the purchase of Notes or
could attempt to refinance the borrowings that contain such prohibition. If the
Company does not obtain such a consent or repay such borrowings, the Company
will remain prohibited from purchasing Notes. In such case, the Company's
failure to purchase tendered Notes would constitute an Event of Default under
the Indenture which would, in turn, constitute a default under the Senior Credit
Facility. In such circumstances, the subordination provisions in the Indenture
would likely restrict payments to the Holders of Notes.
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The Company will not be required to make a Change of Control Offer upon a
Change of Control if a third party makes the Change of Control Offer in the
manner, at the times and otherwise in compliance with the requirements set forth
in the Indenture applicable to a Change of Control Offer made by the Company and
purchases all Notes validly tendered and not withdrawn under such Change of
Control Offer.
Asset Sales. The Indenture provides that the Company will not, and will not
permit any of its Restricted Subsidiaries to, engage in an Asset Sale unless (i)
the Company or such Restricted Subsidiary, as the case may be, receives
consideration at the time of such Asset Sale at least equal to the fair market
value (which shall be determined in good faith by the Company's Board of
Directors) of the assets or Equity Interests issued or sold or otherwise
disposed of and (ii) at least 75% of the consideration therefor received by the
Company or such Restricted Subsidiary is in the form of, or any combination of,
(A) cash or Cash Equivalents, (B) the assumption of any liabilities (as shown on
the Company's or such Restricted Subsidiary's most recent balance sheet) of the
Company or any Restricted Subsidiary of the Company (other than liabilities that
are by their terms subordinated to the Notes or any Subsidiary Guarantee) by the
transferee of any such assets pursuant to a customary novation agreement that
releases the Company or such Restricted Subsidiary from further liability and
(C) any securities, notes or other obligations received by the Company or any
such Restricted Subsidiary from such transferee that are converted by the
Company or such Restricted Subsidiary into cash or Cash Equivalents within 30
days following their receipt (to the extent of cash or Cash Equivalents
received); provided, that any Asset Sale pursuant to a condemnation,
appropriation or other similar taking, including by deed in lieu of
condemnation, or pursuant to the foreclosure or other enforcement of a Lien
incurred not in violation of the covenant described under the caption "-- Liens"
or exercise by the related lienholder of rights with respect thereto, including
by deed or assignment in lieu of foreclosure shall not be required to satisfy
the conditions set forth in clauses (i) and (ii) of this paragraph.
Within 365 days after the receipt of any Net Proceeds from an Asset Sale,
the Company or such Restricted Subsidiary, as the case may be, may apply such
Net Proceeds, at its option, (a) to permanently repay term loans that constitute
Senior Debt, and if no term Senior Debt is outstanding at such time, to repay
outstanding revolving borrowings that constitute Senior Debt, (b) to acquire a
controlling interest in another business or all or substantially all of the
assets of a business, in each case engaged in a Permitted Business, (c) to
acquire other non-current assets to be used in a Permitted Business, including,
without limitation, assets or Investments of the nature or type described in
clause (m) of the definition of "Permitted Investments," provided, that the
Company or such Restricted Subsidiary will have complied with clause (b) or (c)
if, within 365 days of such Asset Sale, the Company or such Restricted
Subsidiary shall have commenced and not completed or abandoned an expenditure or
Investment, or a binding agreement with respect to an expenditure or Investment,
in compliance with clause (b) or (c) and such expenditure or Investment is
substantially completed within a date one year and six months after the date of
such Asset Sale. Pending the final application of any such Net Proceeds, the
Company may temporarily reduce Indebtedness under any Credit Facility or
otherwise expend or invest such Net Proceeds in any manner that is not
prohibited by the Indenture. Any Net Proceeds from Asset Sales that are not
applied or invested as provided in the first sentence of this paragraph shall be
deemed to constitute "Excess Proceeds." When the aggregate amount of Excess
Proceeds exceeds $10 million, the Company shall be required to make an offer to
all Holders of Notes and holders of each other Indebtedness that ranks by its
terms pari passu in right of payment with the Notes and the terms of which
contain substantially similar requirements with respect to the application of
net proceeds from asset sales as are contained in the Indenture (an "Asset Sale
Offer") to purchase on a pro rata basis (with the Excess Proceeds prorated
between the Holders and such holders of pari passu Indebtedness based upon
outstanding aggregate principal amounts) the maximum principal amount of the
Notes, that is an integral multiple of $1,000, that may be purchased out of such
prorated Excess Proceeds, at an offer price in cash in an amount equal to 100%
of the principal amount thereof plus accrued and unpaid interest and Liquidated
Damages thereon, if any, to the date of purchase, in accordance with the
procedures set forth in the Indenture. To the extent that the aggregate amount
of Notes and other such Indebtedness tendered pursuant to an Asset Sale Offer is
less than the Excess Proceeds, the Company and its Restricted Subsidiaries may
use any remaining Excess Proceeds for general corporate purposes and any other
purpose not prohibited by the Indenture. If the aggregate principal amount of
Notes surrendered by Holders thereof exceeds the
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amount of such prorated Excess Proceeds, the Trustee shall select the Notes to
be purchased on a pro rata basis. Upon completion of such offer to purchase, the
amount of Excess Proceeds shall be reset at zero.
CERTAIN COVENANTS
Restricted Payments. The Company will not, and will not permit any of its
Restricted Subsidiaries to, directly or indirectly: (i) declare or pay any
dividend or make any other payment or distribution on account of the Company's
or any of its Restricted Subsidiaries' Equity Interests (including, without
limitation, any payment in connection with any merger or consolidation involving
the Company) or to the direct or indirect holders of the Company's or any of its
Restricted Subsidiaries' Equity Interests in their capacity as such, in each
case other than dividends or distributions payable in Equity Interests (other
than Disqualified Stock) of the Company or declared or paid to the Company or
any of its Restricted Subsidiaries; (ii) purchase, redeem or otherwise acquire
or retire for value (including without limitation, in connection with any merger
or consolidation involving the Company) any Equity Interests of the Company
(other than any such Equity Interests owned by a Wholly Owned Restricted
Subsidiary of the Company); (iii) make any payment to purchase, redeem, defease
or otherwise acquire or retire for value any Indebtedness that is subordinated
to the Notes, except a payment of interest or principal at its Stated Maturity;
or (iv) make any Restricted Investment (all such payments and other actions set
forth in clauses (i) through (iv) above being collectively referred to as
"Restricted Payments"), unless, at the time of and after giving effect to such
Restricted Payment:
(a) no Default or Event of Default shall have occurred and be
continuing; and
(b) the Company would, at the time of such Restricted Payment and
after giving pro forma effect thereto as if such Restricted Payment had
been made at the beginning of the applicable four-quarter period, have been
permitted to incur at least $1.00 of additional Indebtedness pursuant to
the Fixed Charge Coverage Ratio test set forth in the first paragraph of
the covenant described below under the caption "-- Certain
Covenants -- Incurrence of Indebtedness and Issuance of Preferred Stock";
and
(c) such Restricted Payment, together with the aggregate amount of all
other Restricted Payments made by the Company or any of its Restricted
Subsidiaries after the Issue Date (excluding Restricted Payments permitted
by clauses (ii), (iii), (iv), (v), (vi), (viii), or (ix) of the next
succeeding paragraph), is less than the sum of (i) 50% of the Consolidated
Net Income of the Company for the period (taken as one accounting period)
from the beginning of the first fiscal quarter commencing immediately
following the Issue Date to the end of the Company's most recently ended
fiscal quarter for which internal financial statements are available at the
time of such Restricted Payment (or, if such Consolidated Net Income for
such period is a loss, less 100% of such loss), plus (ii) 100% of the
aggregate net cash proceeds, or the Fair Market Value of assets or property
other than cash, received by the Company from the issue or sale, in either
case, since the Issue Date of (A) Equity Interests of the Company (other
than Disqualified Stock), or (B) Disqualified Stock or debt securities of
the Company that have been converted into, or exchanged for, such Equity
Interests, together with the aggregate cash received at the time of such
conversion or exchange, or received by the Company from any such conversion
or exchange of such debt securities sold or issued prior to the Issue Date
other than Equity Interests (or Disqualified Stock or convertible or
exchangeable debt securities) sold to a Restricted Subsidiary of the
Company and other than Disqualified Stock or debt securities that have been
converted or exchanged into Disqualified Stock, plus (iii) in case any
Unrestricted Subsidiary has been redesignated a Restricted Subsidiary
pursuant to the terms of the Indenture or has been merged, consolidated or
amalgamated with or into, or transfers or conveys assets to or is
liquidated into, the Company or a Restricted Subsidiary and provided that
no Default or Event of Default shall have occurred and be continuing or
would occur as a consequence thereof, the lesser of (A) the book value
(determined in accordance with GAAP) at the date of such redesignation,
combination or transfer of the aggregate Investments made by the Company
and its Restricted Subsidiaries in such Unrestricted Subsidiary (or of the
assets transferred or conveyed, as applicable) and (B) the fair market
value of such Investment in such Unrestricted Subsidiary at the time of
such redesignation, combination or transfer (or of the assets transferred
or conveyed, as applicable), in each case as determined in good faith by
the Board of
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Directors of the Company, whose determination shall be conclusive and
evidenced by a resolution of such Board and, in each case, after deducting
any Indebtedness of the Unrestricted Subsidiary so designated or combined
or with the assets so transferred or conveyed, plus (iv) to the extent not
already included in Consolidated Net Income for such period, (A) if any
Restricted Investment that was made by the Company or any Restricted
Subsidiary after the Issue Date is sold for cash or otherwise liquidated or
repaid for cash, the cash return of capital with respect to such Restricted
Investment resulting from such sale or disposition (less the cost of
disposition, if any) and (B)with respect to any Restricted Investment that
was made by the Company or any Restricted Subsidiary after the Issue Date,
the net reduction in such Restricted Investment resulting from payments of
interest, dividends, principal repayments and other transfers and
distributions of cash, assets or property, in an amount not to exceed the
aggregate amount of such Restricted Investment, plus (v) $50 million.
The foregoing provisions shall not prohibit (i) the payment of any dividend
within 60 days after the date of declaration thereof, if at said date of
declaration such payment would have complied with the provisions of the
Indenture, including the immediately preceding paragraph; (ii) the redemption,
repurchase, retirement, defeasance or other acquisition, prior to its Stated
Maturity, of any (y) Indebtedness (or portion thereof) which is subordinated to
the Notes, or the making of any principal payment thereon, or (z) Equity
Interests of the Company or any Restricted Subsidiary, in each case in exchange
for, or out of the net cash proceeds of the substantially concurrent sale or
issuance (other than to a Restricted Subsidiary of the Company) of, Equity
Interests of the Company (other than any Disqualified Stock), provided that the
amount of any such net cash proceeds that are utilized for any such redemption,
repurchase, retirement, defeasance or other acquisition, or payments, shall be
excluded from clause (c)(ii) of the preceding paragraph; (iii) the making of any
principal payment on, or the defeasance, redemption, repurchase or other
acquisition of, prior to its Stated Maturity, Indebtedness which is subordinated
to the Notes with the net cash proceeds from an incurrence of, or in exchange
for the issuance of, Permitted Refinancing Indebtedness; (iv) the payment of any
dividend or distribution by a Restricted Subsidiary of the Company to the
holders of its common Equity Interests on a pro rata basis; (v) the repurchase,
redemption or other acquisition or retirement for value of any Equity Interests
of the Company or any Restricted Subsidiary of the Company held by any current
or former officer, employee or director of the Company (or any of its
Subsidiaries) pursuant to the terms of agreements (including employment
agreements) and plans approved by the Company's Board of Directors, including
any management equity plan or stock option plan or any other management or
employee benefit plan, agreement or trust, provided, however, that the aggregate
price paid for all such repurchased, redeemed, acquired or retired Equity
Interests pursuant to this clause (v) shall not exceed the sum of (y) $1 million
in any twelve-month period and (z) the aggregate net proceeds received by the
Company during such 12-month period from issuance of such Equity Interests
pursuant to such agreements or plans; (vi) repurchases of Equity Interests
deemed to occur upon the cashless exercise of stock options; (vii) the purchase,
redemption, defeasance or retirement, in each case prior to its Stated Maturity,
of any Indebtedness that is subordinated to the Notes in right of payment by
payments out of Excess Proceeds remaining after completion of an Asset Sale
Offer, provided that (x) any payments made or value given for such purchase,
redemption, defeasance or retirement shall be made out of, or shall not be in
excess of, any Excess Proceeds remaining after completion of an Asset Sale Offer
(but for the provision of the last sentence under the caption "-- Repurchase at
the Option of Holders -- Asset Sales") and (y) the Company would, at the time of
such payment and after giving pro forma effect thereto as if such payment had
been made at the beginning of the applicable four-quarter period, have been
permitted to incur at least $1.00 of additional Indebtedness pursuant to the
Fixed Charge Coverage Ratio test set forth in the first paragraph of the
covenant described below under the caption "-- Certain Covenants -- Incurrence
of Indebtedness and Issuance of Preferred Stock"; (viii) reasonable and
customary directors' fees to the members of the Company's Board of Directors,
provided that such fees are consistent with past practice or current
requirements; and (ix) cash dividends declared or paid in respect of shares of
Mandatorily Convertible Preferred Stock of the Company issued on or prior the
Issue Date (together with any additional shares issued in respect of any
underwriters' over-allotment option in effect on the Issue Date); provided,
further, that, with respect to clauses (ii), (iii), (v), (vi), (vii), (viii) and
(ix) above, no Default or Event of Default shall have occurred and be
continuing.
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In determining whether any Restricted Payment is permitted by the foregoing
covenant, the Company may allocate or reallocate all or any portion of such
Restricted Payment among the clauses (i) through (ix) of the preceding paragraph
or among such clauses and the first paragraph of this covenant including clauses
(a), (b) and (c), provided that at the time of such allocation or reallocation,
all such Restricted Payments, or allocated portions thereof, would be permitted
under the various provisions of the foregoing covenant.
The amount of all Restricted Payments (other than cash) shall be the Fair
Market Value (as determined by the Board of Directors of the Company and as
evidenced by a resolution of the Board of Directors of the Company set forth in
an Officers' Certificate delivered to the Trustee) on the date of the transfer,
incurrence or issuance of such non-cash Restricted Payment. Not later than (i)
the end of any calendar quarter in which any Restricted Payment is made or (ii)
the making of a Restricted Payment which, when added to the sum of all previous
Restricted Payments made in a calendar quarter, would cause the aggregate of all
Restricted Payments made in such quarter to exceed $10 million, the Company
shall deliver to the Trustee an Officers' Certificate stating that such
Restricted Payments were permitted and setting forth the basis upon which the
calculations required by this covenant were computed, which calculations may be
based upon the Company's latest available financial statements.
The Board of Directors may designate any Unrestricted Subsidiary to be a
Restricted Subsidiary only if (i) immediately after giving effect to such
designation, the Company could incur $1.00 of additional Indebtedness pursuant
to the Fixed Charge Coverage Ratio test under the first paragraph of the
covenant described below under the caption "-- Certain Covenants -- Incurrence
of Indebtedness and Issuance of Preferred Stock", (ii) immediately before and
immediately after giving effect to such designation, no Default or Event of
Default shall have occurred and be continuing and (iii) the Company certifies
that such designation complies with this covenant. Any such designation by the
Board of Directors shall be evidenced by the Company promptly filing with the
Trustee a copy of the resolution giving effect to such designation and an
Officers' Certificate certifying that such designation complied with the
foregoing provisions.
The Board of Directors may designate any Subsidiary of the Company to be an
Unrestricted Subsidiary under the circumstances and pursuant to the requirements
described in the definition of "Unrestricted Subsidiary," which requirements
include that such designation will be made in compliance with this covenant. For
purposes of making the determination as to whether such designation would be
made in compliance with this covenant, all outstanding Investments by the
Company and its Restricted Subsidiaries (except to the extent repaid in cash) in
the Subsidiary so designated will be deemed to be Restricted Payments at the
time of such designation and will reduce the amount available for Restricted
Payments under the first paragraph of this covenant. All such outstanding
Investments will be deemed to constitute Investments in an amount equal to the
greatest of (i) the net book value (determined in accordance with GAAP) of such
Investments at the time of such designation, (ii) the Fair Market Value of such
Investments at the time of such designation and (iii) the original Fair Market
Value of such Investments at the time they were made.
Incurrence of Indebtedness and Issuance of Preferred Stock. The Indenture
provides that the Company will not, and will not permit any of its Restricted
Subsidiaries to, directly or indirectly, create, incur, issue, assume, guarantee
or otherwise become directly or indirectly liable, contingently or otherwise,
with respect to (collectively, "incur") any Indebtedness (including Acquired
Debt), other than Permitted Debt, and the Company shall not issue any
Disqualified Stock and shall not permit any of its Restricted Subsidiaries to
issue any shares of preferred stock other than Permitted Debt; provided,
however, that the Company or any Guarantor may incur Indebtedness (including
Acquired Debt) or the Company may issue shares of Disqualified Stock if the
Company's Fixed Charge Coverage Ratio for the Company's most recently ended four
full fiscal quarters for which internal financial statements are available
immediately preceding the date on which such additional Indebtedness is incurred
or such Disqualified Stock is issued would have been at least 2.00 to 1,
determined on a pro forma basis (including a pro forma application of the net
proceeds therefrom), as if the additional Indebtedness had been incurred, or the
Disqualified Stock had been issued, as the case may be, at the beginning of such
four-quarter period.
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The provisions of the first paragraph of this covenant shall not apply to
the incurrence of any of the following items of Indebtedness (collectively,
"Permitted Debt"):
(i) the incurrence by the Company and the Guarantors of Indebtedness
represented by the Notes, the Exchange Notes and the Subsidiary Guarantees;
(ii) the incurrence by the Company or any Guarantor of Indebtedness
and letters of credit pursuant to the Senior Credit Facility (with letters
of credit being deemed to have a principal amount equal to the maximum
potential liability of the Company or its Restricted Subsidiaries for
reimbursement obligations thereunder) in an aggregate principal amount not
to exceed $500 million at any one time outstanding, less the aggregate
amount of all proceeds of Asset Sales that have been applied since the
Issue Date to permanently reduce the outstanding amount of such
Indebtedness pursuant to the covenant described above under the caption
"-- Repurchase at the Option of Holders -- Asset Sales";
(iii) the incurrence by the Company or any of its Restricted
Subsidiaries of Existing Indebtedness;
(iv) the incurrence by the Company or any of its Restricted
Subsidiaries of Permitted Refinancing Indebtedness in exchange for, or the
net proceeds of which are used to extend, refinance, renew, replace,
defease or refund, Indebtedness that was permitted by the Indenture to be
incurred;
(v) the incurrence by the Company or any of its Restricted
Subsidiaries of intercompany Indebtedness between or among the Company and
any of its Restricted Subsidiaries; provided, however, that (i) if the
Company is the obligor, or any Guarantor is the obligor and the Company is
not the obligee, on such Indebtedness, such Indebtedness is expressly
subordinate to the payment in full of all Obligations with respect to the
Notes and (ii) (A) any subsequent issuance or transfer of Equity Interests
that results in any such Indebtedness being held by a Person other than the
Company or a Restricted Subsidiary and (B) any sale or other transfer of
any such Indebtedness to a Person that is not either the Company or a
Restricted Subsidiary shall be deemed, in each case, to constitute an
incurrence of such Indebtedness by the Company or such Restricted
Subsidiary, as the case may be;
(vi) the incurrence by the Company or any of its Restricted
Subsidiaries of Indebtedness represented by Capital Lease Obligations,
mortgage financings or purchase money obligations, in each case incurred
for the purpose of financing all or any part of the purchase price or cost
of construction or improvement of property, plant or equipment used in the
Permitted Business (including, without limitation, oil and gas properties)
of the Company or a Restricted Subsidiary or incurred to extend, refinance,
renew, replace, defease or refund any such purchase price or cost of
construction or improvement, in each case in an aggregate principal amount
not to exceed $50 million at any time outstanding, provided that, in each
case, such Indebtedness is incurred within 30 days of the later of the date
of purchase or the date of completion of such construction or improvement;
(vii) the incurrence by the Company or any of its Restricted
Subsidiaries of Indebtedness incurred in the ordinary course of business
under (A) documentary letters of credit, or surety bonds or insurance
contracts, which are to be repaid in full not more than one year after the
date on which such Indebtedness is originally incurred to finance the
purchase of goods by the Company or a Restricted Subsidiary of the Company,
provided that the amount of such Indebtedness shall not exceed $20 million
at any time outstanding, (B) standby letters of credit, surety bonds or
insurance contracts issued for the purpose of supporting (1) workers'
compensation or similar liabilities of the Company or any of its Restricted
Subsidiaries, or (2) performance, payment, deposit or surety obligations of
the Company or any of its Restricted Subsidiaries and (C) bid, advance
payment and performance bonds and surety bonds, or similar insurance
contracts, for the Company and its Restricted Subsidiaries, and
refinancings thereof;
(viii) the incurrence by the Company or any of its Restricted
Subsidiaries of Indebtedness consisting of (A) Financial Hedging
Obligations that are either (1) incurred for the purpose of fixing or
hedging interest rate risk related to Indebtedness permitted to be incurred
by the Company or its Restricted Subsidiaries pursuant to the Indenture,
but only to the extent that the stated aggregate notional amounts
thereunder do not exceed 105% of the aggregate principal amount of the
Indebtedness to which such obligations relate or (2) incurred in the
ordinary course of business for the purpose of
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limiting or managing currency exchange risks, and (B) Commodity Hedging
Obligations in connection with the conduct of a Permitted Business, and, in
the case of each of clauses (A) and (B) hereof, not for speculative
purposes;
(ix) the incurrence by the Company or any of its Restricted
Subsidiaries of in-kind obligations relating to overproduced gas balancing
positions arising in the ordinary course of business;
(x) Indebtedness arising from agreements of the Company or any of its
Restricted Subsidiaries providing for indemnification, adjustment of
purchase price or similar obligations, in each case, incurred in connection
with the disposition or acquisition of any business, assets or a Restricted
Subsidiary of the Company or any of its Restricted Subsidiaries, other than
guarantees of Indebtedness incurred by any Person acquiring all or any
portion of such business, assets or a Restricted Subsidiary of the Company
or any of its Restricted Subsidiaries for the purposes of financing such
acquisition; provided, however, that (A) such Indebtedness is not reflected
on the balance sheet of the Company or any of its Restricted Subsidiaries
(contingent obligations referred to in a footnote to financial statements
and not otherwise reflected on the balance sheet will not be deemed to be
reflected on such balance sheet for purposes of this clause (A)) and (B)
the maximum liability in respect of all such Indebtedness shall at no time
exceed the gross proceeds including non-cash proceeds (the Fair Market
Value of such non-cash proceeds being measured at the time received and
without giving effect to any subsequent changes in value) actually received
by the Company and its Restricted Subsidiaries in connection with such
disposition;
(xi) the guarantee by the Company or any of the Guarantors of
Indebtedness of the Company or a Restricted Subsidiary of the Company that
was permitted to be incurred by any provision of this covenant other than
this clause (xi); provided, that the guarantee of any Indebtedness of a
Restricted Subsidiary of the Company that ceases to be such a Restricted
Subsidiary shall be deemed a Restricted Investment at the time such
Restricted Subsidiary's status terminates in an amount equal to the maximum
principal amount so guaranteed, for so long as, and to the extent that,
such guarantee remains outstanding;
(xii) the issuance by a Restricted Subsidiary of the Company of
preferred stock to the Company or to any of its Wholly Owned Restricted
Subsidiaries; provided, however, that any subsequent event or issuance or
transfer of any Equity Interests that results in the owner of such
preferred stock ceasing to be the Company or any of its Wholly Owned
Restricted Subsidiaries or any subsequent transfer of such preferred stock
to a Person, other than the Company or one of its Restricted Subsidiaries,
shall be deemed to be an issuance of preferred stock by such Subsidiary
that was not permitted by this clause (xii); and
(xiii) the incurrence by the Company or any of its Restricted
Subsidiaries of Indebtedness (in addition to Indebtedness permitted by any
other clause of this paragraph) in an aggregate principal amount (or
accreted value, as applicable) at any time outstanding not to exceed $50
million.
For purposes of determining compliance with this covenant, in the event
that an item of Indebtedness meets the criteria of more than one of the
categories of Permitted Debt described above or is entitled to be incurred
pursuant to the first paragraph of this covenant, the Company will, in its sole
discretion, classify such item of Indebtedness in any manner that complies with
this covenant and such item of Indebtedness or a portion thereof may be
classified as having been incurred under more than one of the applicable clauses
or pursuant to the first paragraph hereof. Accrual of interest, the accretion of
accreted value and the payment of interest in the form of additional
Indebtedness will not be deemed to be an incurrence of Indebtedness for purposes
of this covenant.
Liens. The Indenture provides that the Company will not, and will not
permit any of its Restricted Subsidiaries to, directly or indirectly, create,
incur, assume or suffer to exist any Lien that secures obligations under any
Indebtedness which is pari passu with or subordinated to the Notes, unless the
Notes are equally and ratably secured with the obligations so secured or until
such time as such obligations are no longer secured by a Lien.
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Dividend and Other Payment Restrictions Affecting Subsidiaries. The
Indenture provides that the Company will not, and will not permit any of its
Restricted Subsidiaries to, directly or indirectly, create or otherwise cause or
suffer to exist or become effective any encumbrance or restriction on the
ability of any Restricted Subsidiary of the Company or the Company to (i)(x) pay
dividends or make any other distributions to the Company or any of its
Restricted Subsidiaries (1) on its Capital Stock or (2) with respect to any
other interest or participation in, or measured by, its profits, or (y) pay any
Indebtedness owed to the Company or any of its Restricted Subsidiaries, (ii)
make loans or advances to the Company or any of its Restricted Subsidiaries or
(iii) transfer any of its properties or assets to the Company or any of its
Restricted Subsidiaries, except for such encumbrances or restrictions existing
under or by reason of (a) the Indenture, the Notes, Existing Indebtedness and
the Senior Credit Facility as in effect on the Issue Date, any other Credit
Facility hereafter in effect provided to the extent its provisions are no more
restrictive than those in the Senior Credit Facility as it is in effect on the
Issue Date and any future Liens that may be permitted to be granted under, or
incurred not in violation of, any other provisions of the Indenture, (b)
applicable law, (c) any instrument governing Indebtedness or Capital Stock of a
Person acquired by the Company or any of its Restricted Subsidiaries as in
effect at the time of such acquisition (except with respect to Indebtedness
incurred in connection with or in contemplation of such acquisition), which
encumbrance or restriction is not applicable to any Person, or the properties or
assets of any Person, other than the Person, or the property or assets of the
Person or such Person's subsidiaries, so acquired, provided that, in the case of
Indebtedness, such Indebtedness was permitted by the terms of the Indenture to
be incurred, (d) restrictions of the nature described in clause (iii) above by
reason of customary non-assignment provisions in contracts, agreements, and
leases entered into in the ordinary course of business and consistent with
customary provisions for the sale of property, (e) purchase money obligations
for property acquired in the ordinary course of business that impose
restrictions of the nature described in clause (iii) above on the property so
acquired, (f) any restriction with respect to a Restricted Subsidiary of the
Company imposed pursuant to an agreement entered into for the sale or
disposition of all or substantially all of the Capital Stock or assets of such
Restricted Subsidiary pending the closing of such sale or disposition, (g)
agreements relating to secured Indebtedness otherwise permitted to be incurred
pursuant to the covenant described under the caption "-- Incurrence of
Indebtedness and Issuance of Preferred Stock," and not in violation of the
covenant described under caption "-- Liens," that limit the right of the debtor
to dispose of assets securing such Indebtedness and (h) Permitted Refinancing
Indebtedness in respect of Indebtedness referred to in clause (a), (c), (e) and
(g) of this paragraph, provided that the restrictions contained in the
agreements governing such Permitted Refinancing Indebtedness are no more
restrictive than those contained in the agreements governing the Indebtedness
being refinanced.
Merger, Consolidation, or Sale of Assets. The Indenture provides that the
Company will not consolidate or merge with or into, or sell, assign, transfer,
lease, convey or otherwise dispose of all or substantially all of the properties
or assets in one or more related transactions, to another Person unless (i) the
Company is the resulting, transferee or surviving Person or the resultant,
transferee or surviving Person (if other than the Company) shall be a
corporation organized or existing under the laws of the United States, any state
thereof or the District of Columbia; (ii) the resulting transferee or surviving
Person (if other than the Company) assumes all the obligations and covenants of
the Company under the Notes and the Indenture pursuant to a supplemental
indenture in a form reasonably satisfactory to the Trustee; (iii) immediately
before and after such transaction no Default or Event of Default shall have
occurred and be continuing; and (iv) except in the case of a merger of the
Company with or into a Wholly Owned Restricted Subsidiary, the Company or the
resultant, transferee or surviving Person (if other than the Company) (A) will
have Consolidated Net Worth immediately after the transaction equal to or
greater than the Consolidated Net Worth of the Company immediately preceding the
transaction and (B) will, at the time of such transaction and after giving pro
forma effect thereto as if such transaction had occurred at the beginning of the
applicable four-quarter period, be permitted to incur at least $1.00 of
additional Indebtedness pursuant to the Fixed Charge Coverage Ratio test set
forth in the first paragraph of covenant described above under the caption
"-- Incurrence of Indebtedness and Issuance of Preferred Stock."
Upon any transaction or series of transactions that are of the type
described in, and are effected in accordance with, the foregoing paragraph, the
surviving Person (if other than the Company) shall succeed to,
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and be substituted for, and may exercise every right and power of, the Company
under the Indenture and the Notes with the same effect as if such surviving
Person had been named as the Company in the Indenture; and when a surviving
Person duly assumes all of the obligations and covenants of the Company pursuant
to the Indenture and the Notes, except in the case of a lease of all or
substantially all of the properties or assets in one or more related
transactions, the predecessor Person shall be relieved of all such obligations.
Additional Subsidiary Guarantees. The Indenture provides that (i) if any
Subsidiary of the Company guarantees any Indebtedness of the Company, then such
Subsidiary shall (a) execute a supplemental indenture in form and substance
satisfactory to the Trustee providing that such Subsidiary shall become a
Guarantor under the Indenture and (b) deliver an opinion of counsel to the
effect that such supplemental indenture has been duly authorized and executed by
such Subsidiary and (ii) upon (x) the release by the lenders of all guarantees
of a Guarantor guaranteeing, and all Liens on the property and assets of such
Guarantor securing, Indebtedness of the Company, or (y) a sale or other
disposition, whether in one or a series of related transactions, of all or
substantially all of the assets of any Guarantor, by way of merger,
consolidation or otherwise, or a sale or other disposition, whether in one or a
series of related transactions, of all of the Capital Stock of any Guarantor in
compliance with the Indenture to any entity that is not the Company or a
Subsidiary, then such Guarantor and such acquiring, resulting, surviving or
transferee Person will be released and relieved of any obligations under any
Subsidiary Guarantee; provided, however, that any such termination shall occur
only to the extent that all obligations of such Guarantor under such
Indebtedness and all of its guarantees of, and under all of its pledges of
assets or other security interests which secure, Indebtedness of the Company
shall also terminate upon such release, sale or transfer and, in the event of
any sale or other disposition, delivery of an Officers' Certificate to the
Trustee that the Net Proceeds of such sale or other disposition will be applied
in accordance with the applicable provisions of the Indenture. See
"-- Repurchase at the Option of Holders -- Asset Sales."
Transactions with Affiliates. The Indenture provides that the Company will
not, and will not permit any of its Restricted Subsidiaries to, directly or
indirectly, make any payment to, or sell, lease, transfer or otherwise dispose
of any properties or assets to, or purchase any property or assets from, or
enter into or make or amend any transaction, contract, agreement, understanding,
loan, advance or guarantee with, or for the benefit of, any Affiliate of any
such Person (each of the foregoing, an "Affiliate Transaction"), unless (i) such
Affiliate Transaction is on terms that are no less favorable to the Company or
the relevant Restricted Subsidiary than those that could have been obtained in a
comparable transaction by the Company or such Restricted Subsidiary with an
unrelated Person and (ii) the Company delivers to the Trustee (a) with respect
to any Affiliate Transaction or series of related Affiliate Transactions
involving aggregate consideration in excess of at least $1 million, an Officers'
Certificate certifying that such Affiliate Transaction complies with clause (i)
above, (b) with respect to any Affiliate Transaction or series of related
Affiliate Transactions involving aggregate consideration in excess of $10
million, a resolution of its Board of Directors set forth in an Officers'
Certificate certifying that such Affiliate Transaction complies with clause (i)
above and that such Affiliate Transaction has been approved by a majority of the
disinterested members of its Board of Directors and (c) with respect to any
Affiliate Transaction or series of related Affiliate Transactions involving
aggregate consideration in excess of $10 million and for which there are no
disinterested members of its Board of Directors, an opinion as to the fairness
to the Holders of such Affiliate Transaction from a financial point of view
issued by an Independent Financial Advisor; provided that none of the following
shall be deemed to be Affiliate Transactions: (1) Affiliate Transactions
involving the purchase or sale of crude oil, natural gas and other hydrocarbons,
and refined products therefrom, in the ordinary course of any Permitted
Business, so long as such transactions are priced in line with industry accepted
benchmark prices and the pricing of such transactions are equivalent to the
pricing of comparable transactions with unrelated third parties, (2) any
employment agreement or other employee compensation plan or arrangement entered
into by the Company or any of its Restricted Subsidiaries in the ordinary course
of business, (3) transactions between or among (A) the Company and its
Restricted Subsidiaries and (B) the Restricted Subsidiaries, (4) fees and
compensation paid to, and indemnity provided on behalf of, officers, directors,
employees or consultants of the Company and of its Restricted Subsidiaries in
their capacity as such, to the extent such fees and compensation are reasonable
and customary, (5) loans or advances to officers, directors and employees for
moving, entertainment and travel expenses, drawing accounts and similar
expenditures and other purposes, in each
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case in the ordinary course of business, (6) maintenance in the ordinary course
of business of customary benefit programs or arrangements for employees,
officers or directors, including vacation plans, health and life insurance
plans, deferred compensation plans and retirement or savings plans and similar
plans, and (7) fees and compensation paid to, and indemnity provided on behalf
of, officers, directors or employees of the Company or any of its Restricted
Subsidiaries, as determined by the Board of Directors of the Company or of any
such Restricted Subsidiary, to the extent such fees and compensation are
reasonable and customary as determined by the Board of Directors of the Company
or such Restricted Subsidiary.
No Senior Subordinated Debt. The Indenture provides that, notwithstanding
any other provision thereof, (i) the Company will not incur, create, issue,
assume, guarantee or otherwise become liable directly or indirectly for any
Indebtedness (including Acquired Debt) that is expressly subordinate or junior
in right of payment to any Senior Debt of the Company and senior in any respect
in right of payment to the Notes and (ii) no Guarantor will incur, create,
issue, assume, guarantee or otherwise become liable for any Indebtedness
(including Acquired Debt) that is expressly subordinate or junior in right of
payment to any Senior Debt of a Guarantor and senior in any respect in right of
payment to the Subsidiary Guarantees, it being understood that Indebtedness will
not be considered senior to other Indebtedness solely by reason of being
secured.
Limitation on Issuances and Sales of Capital Stock of Subsidiaries. The
Indenture provides that the Company (i) will not, and will not permit any Wholly
Owned Restricted Subsidiary of the Company to, transfer, convey, sell or
otherwise dispose of any Capital Stock of any Wholly Owned Restricted Subsidiary
of the Company to any Person (other than the Company or a Wholly Owned
Restricted Subsidiary of the Company), unless (a) such transfer, conveyance,
sale, lease or other disposition is of all the Capital Stock of such Restricted
Subsidiary and (b) the net proceeds from such transfer, conveyance, sale, lease
or other disposition are applied in accordance with the covenant described above
under the caption "-- Repurchase at the Option of Holders -- Asset Sales," and
(ii) will not permit any Wholly Owned Restricted Subsidiary of the Company to
issue any of its Equity Interests to any Person other than to the Company or a
Wholly Owned Restricted Subsidiary of the Company, subject to dispositions and
issuances permitted by clauses (i) and (ii) of the definition of "Wholly Owned
Restricted Subsidiary."
Business Activities. The Indenture provides that the Company will not, and
the Company will not permit any of its Restricted Subsidiaries to, engage in any
business other than a Permitted Business, except to such extent as would not be
material to the Company and its Restricted Subsidiaries taken as a whole.
Payments for Consent. The Indenture provides that the Company will not, and
will not permit any of its Restricted Subsidiaries to, directly or indirectly,
pay or cause to be paid any consideration, whether by way of interest, fee or
otherwise, to any Holder of any Notes for or as an inducement to any consent,
waiver or amendment of any of the terms or provisions of the Indenture or the
Notes unless such consideration is offered to be paid or agreed to be paid to
all Holders of the Notes that consent, waive or agree to amend in the time frame
set forth in the solicitation documents relating to such consent, waiver or
agreement.
Reports. The Indenture provides that whether or not the Company is required
by the rules and regulations of the Commission, so long as any Notes are
outstanding, the Company will furnish to each of the Holders of Notes (i) all
quarterly and annual financial information with respect to the Company and its
Subsidiaries that would be required to be contained in a filing with the
Commission on Forms 10-Q and 10-K if the Company were required to file such
forms, including a "Management's Discussion and Analysis of Financial Condition
and Results of Operations" and, with respect to the annual information only, a
report thereon by the Company's independent public accountants and (ii) all
current reports that would be required to be filed with the Commission on Form
8-K if the Company were required to file such reports. All such information and
reports shall be mailed or otherwise delivered to the Holders of Notes within 15
days after the dates on which such filings would have been required to be made
had the Company been subject to the rules and regulations of the Commission. In
addition, whether or not required by the rules and regulations of the
Commission, the Company shall file a copy of all such information and reports
with the Commission for public availability within the time periods specified in
the Commission's rules and regulations (unless the Commission will not accept
such a filing) and make such information available to securities analysts and
prospective investors upon request.
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EVENTS OF DEFAULT AND REMEDIES
The Indenture provides that each of the following constitutes an Event of
Default: (i) default for 30 days in the payment when due of interest on, or
Liquidated Damages with respect to, the Notes, (ii) default in payment when due
of the principal of, or premium, if any, on the Notes; (iii) failure by the
Company or any of its Restricted Subsidiaries to comply with the provisions
described under the captions "-- Certain Covenants -- Merger, Consolidation or
Sale of Assets," "-- Special Redemption," "-- Repurchase at the Option of
Holders -- Asset Sales," and "Repurchase at the Option of Holders -- Change of
Control"; (iv) failure by the Company or any of its Restricted Subsidiaries for
60 days after written notice of such failure from the Trustee or the Holders of
at least 25% in aggregate principal amount of outstanding Notes to comply with
any of its other agreements in the Indenture or the Notes; (v) default under any
mortgage, indenture or instrument under which there may be issued or by which
there may be secured or evidenced any Indebtedness for money borrowed by the
Company or any of its Restricted Subsidiaries (or the payment of which is
guaranteed by the Company or any of its Restricted Subsidiaries), whether such
Indebtedness or guarantee now exists, or is created after the Issue Date, which
default (a) is caused by a failure to pay principal of or premium, if any, or
interest on such Indebtedness prior to the expiration of the grace period
provided in such Indebtedness (a "Payment Default") or (b) results in the
acceleration of such Indebtedness prior to its express maturity and, in each
case, the principal amount of any such Indebtedness, together with the principal
amount of any other such Indebtedness under which there has been a Payment
Default or the maturity of which has been so accelerated, aggregates without
duplication $15 million or more, and such default shall not have been cured or
waived or any such acceleration rescinded within ten business days after the
running of such grace period or the occurrence of such acceleration; (vi)
failure by the Company or any of its Restricted Subsidiaries to pay final
judgments aggregating in excess of $15 million (excluding amounts covered by
insurance), which judgments are not paid, discharged or stayed for a period of
60 days; (vii) certain events of bankruptcy or insolvency with respect to the
Company, or any group of Subsidiaries that when taken together, would constitute
a Significant Subsidiary or any Significant Subsidiary upon the occurrence of
such events; and (viii) except as permitted by the Indenture, any Subsidiary
Guarantee shall be held in any judicial proceeding to be unenforceable or
invalid or shall cease for any reason to be in full force and effect or any
Guarantor, or any Person acting on behalf of any such Guarantor, shall deny or
disaffirm its obligations under its Subsidiary Guarantee (other than by reason
of the termination of the Indenture or the release of any such Subsidiary
Guarantee in accordance with the Indenture).
If any Event of Default occurs and is continuing, the Trustee or the
Holders of at least 25% in principal amount of the then outstanding Notes may
declare all the Notes to be due and payable immediately. Notwithstanding the
foregoing, in the case of an Event of Default arising from certain events of
bankruptcy or insolvency, with respect to the Company, any Significant
Subsidiary or any group of Subsidiaries that, taken together, would constitute a
Significant Subsidiary, all outstanding Notes will become due and payable
without further action or notice. Holders of the Notes may not enforce the
Indenture or the Notes except as provided in the Indenture. Subject to certain
limitations, Holders of a majority in principal amount of the then outstanding
Notes may direct the Trustee in its exercise of any trust or power. The Trustee
may withhold from Holders of the Notes notice of any continuing Default or Event
of Default (except a Default or Event of Default relating to the payment of
principal or interest or Liquidated Damages) if it determines that withholding
notice is in their interest.
The Holders of a majority in aggregate principal amount of the Notes then
outstanding by notice to the Trustee may on behalf of the Holders of all of the
Notes (i) waive any existing Default or Event of Default and its consequences
under the Indenture except a continuing Default or Event of Default in the
payment of interest and Liquidated Damages, if any, on, or the principal of, the
Notes and (ii) rescind an acceleration and its consequences if the rescission
would not conflict with any judgment or decree and if all existing Events of
Default (except nonpayment of principal, interest or Liquidated Damages that has
become due solely because of the acceleration) have been cured or waived.
The Company is required to deliver to the Trustee annually a statement
regarding compliance with the Indenture, and the Company is required upon
becoming aware of any Default or Event of Default, to deliver to the Trustee a
statement specifying such Default or Event of Default.
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NO PERSONAL LIABILITY OF DIRECTORS, OFFICERS, EMPLOYEES, INCORPORATOR, MEMBERS,
PARTNERS AND STOCKHOLDERS
No director, officer, employee, incorporator, member, partner or
stockholder or other owner of Capital Stock of the Company or any of its
Subsidiaries, as such, has or shall have any liability for any obligations of
the Company or any Guarantor under the Notes, the Subsidiary Guarantees or the
Indenture or for any claim based on, in respect of, or by reason of, such
obligations or their creation. Each Holder of Old Notes by accepting an Old Note
waived and released all such liability. The waiver and release were part of the
consideration for issuance of the Old Notes. Each holder of Exchange Notes by
accepting an Exchange Note waives and releases all such liability. The waiver
and release are part of the consideration for issuance of the Exchange Notes.
Such waivers may not be effective to waive liabilities under the federal
securities laws, and it is the view of the Commission that such a waiver is
against public policy.
LEGAL DEFEASANCE AND COVENANT DEFEASANCE
The Company may, at its option and at any time, elect to have all of its
obligations discharged with respect to the outstanding Notes ("Legal
Defeasance") except for (i) the rights of Holders of outstanding Notes to
receive payments in respect of the principal of, and premium, if any, and
interest and Liquidated Damages, if any, on such Notes when such payments are
due from the trust referred to below, (ii) the Company's obligations with
respect to the Notes concerning issuing temporary Notes, registration of Notes,
mutilated, destroyed, lost or stolen Notes and the maintenance of an office or
agency for payment and money for security payments held in trust, (iii) the
rights, powers, trusts, duties and immunities of the Trustee, and the Company's
obligations in connection therewith and (iv) the Legal Defeasance provisions of
the Indenture. In addition, the Company may, at its option and at any time,
elect to have the obligations of the Company released with respect to certain
covenants that are described in the Indenture ("Covenant Defeasance") and
thereafter any omission to comply with such obligations shall not constitute a
Default or Event of Default with respect to the Notes. In the event Covenant
Defeasance occurs, certain events (not including non-payment, bankruptcy,
receivership, rehabilitation and insolvency events) described under "Events of
Default" will no longer constitute an Event of Default with respect to the
Notes.
In order to exercise either Legal Defeasance or Covenant Defeasance, (i)
the Company must irrevocably deposit with the Trustee, in trust, for the benefit
of the Holders of the Notes, cash in U.S. dollars, non-callable Government
Securities, or a combination thereof, in such amounts as will be sufficient, in
the opinion of a nationally recognized firm of independent public accountants,
to pay the principal of, and premium, if any, and interest and Liquidated
Damages, if any, on the outstanding Notes on the stated maturity or on the
applicable redemption date, as the case may be, and the Company must specify
whether the Notes are being defeased to maturity or to a particular redemption
date; (ii) in the case of Legal Defeasance, the Company shall have delivered to
the Trustee an opinion of counsel in the United States reasonably acceptable to
the Trustee confirming that (A) the Company has received from, or there has been
published by, the Internal Revenue Service a ruling or (B) since the Issue Date,
there has been a change in the applicable federal income tax law, in either case
to the effect that, and based thereon such opinion of counsel shall confirm
that, the Holders of the outstanding Notes will not recognize income, gain or
loss for federal income tax purposes as a result of such Legal Defeasance and
will be subject to federal income tax on the same amounts, in the same manner
and at the same times as would have been the case if such Legal Defeasance had
not occurred; (iii) in the case of Covenant Defeasance, the Company shall have
delivered to the Trustee an opinion of counsel in the United States reasonably
acceptable to the Trustee confirming that the Holders of the outstanding Notes
will not recognize income, gain or loss for federal income tax purposes as a
result of such Covenant Defeasance and will be subject to federal income tax on
the same amounts, in the same manner and at the same times as would have been
the case if such Covenant Defeasance had not occurred; (iv) no Default or Event
of Default shall have occurred and be continuing on the date of such deposit
(other than a Default or Event of Default resulting from the incurrence of
Indebtedness or the grant of Liens securing such Indebtedness, all or a portion
of the proceeds of which will be used to defease the Notes pursuant to Article
VIII of the Indenture concurrently with such incurrence or within 30 days
thereof) or insofar as Events of Default from bankruptcy or insolvency events
are concerned, at any time in the period ending on the 91st day after the date
of deposit; (v) such deposit will not result in a breach or violation of, or
constitute a default under any material
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agreement or instrument (other than the Indenture) to which the Company or any
of its Restricted Subsidiaries is a party or by which the Company or any of its
Restricted Subsidiaries is bound, or if such breach, violation or default would
occur, which is not waived as of, and for all purposes, on and after, the date
of such deposit; (vi) the Company must have delivered to the Trustee an opinion
of counsel to the effect that after the 91st day following the deposit, the
trust funds will not be subject to the effect of any applicable bankruptcy,
insolvency, reorganization or similar laws affecting creditors' rights
generally; (vii) the Company must deliver to the Trustee an Officers'
Certificate stating that the deposit was not made by the Company with the intent
of preferring the Holders of Notes over the other creditors of the Company with
the intent of defeating, hindering, delaying or defrauding creditors of the
Company or others; and (viii) the Company must deliver to the Trustee an
Officers' Certificate and an opinion of counsel, each stating that all
conditions precedent provided for relating to the Legal Defeasance or the
Covenant Defeasance have been complied with.
SATISFACTION AND DISCHARGE
The Indenture will be discharged and will cease to be of further effect as
to all Notes issued thereunder, when (a) either (i) all such Notes theretofore
authenticated and delivered (except lost, stolen or destroyed Notes which have
been replaced or paid and Notes for whose payment money has heretofore been
deposited in trust and thereafter repaid to the Company) have been delivered to
the Trustee for cancellation; or (ii) all such Notes not theretofore delivered
to such Trustee for cancellation have become due and payable by reason of the
making of a notice of redemption or otherwise or will become due and payable
within one year and the Company has irrevocably deposited or caused to be
deposited with such Trustee as trust funds in trust solely for the benefit of
the Holders, cash in U.S. dollars, non-callable Government Securities, or a
combination thereof, in such amounts as will be sufficient without consideration
of any reinvestment of interest, to pay and discharge the entire indebtedness on
such Notes not theretofore delivered to the Trustee for cancellation for
principal, premium, if any, and accrued interest to the date of maturity or
redemption; (b) no Default or Event of Default with respect to the Indenture or
the Notes shall have occurred and be continuing on the date of such deposit or
shall occur as a result of such deposit and such deposit will not result in a
breach or violation of, or constitute a default under, any other material
instrument to which the Company is a party or by which the Company is bound; (c)
the Company has paid or caused to be paid all sums due and payable by it under
the Indenture; and (d) the Company has delivered irrevocable instructions to the
Trustee under the Indenture to apply the deposited money toward the payment of
such Notes at maturity or the redemption date, as the case may be. In addition,
the Company must deliver an Officers' Certificate and an opinion of counsel to
the Trustee stating that all conditions precedent to satisfaction and discharge
have been satisfied.
TRANSFER AND EXCHANGE
A Holder may transfer or exchange Notes in accordance with the Indenture.
The Registrar and the Trustee may require a Holder, among other things, to
furnish appropriate endorsements and transfer documents and the Company may
require a Holder to pay any taxes and fees required by law or permitted by the
Indenture. The Company is not required to transfer or exchange any Note selected
for redemption. Also, the Company is not required to transfer or exchange any
Note for a period of 15 days before a selection of Notes to be redeemed.
The registered Holder of a Note will be treated as the owner of it for all
purposes.
AMENDMENT, SUPPLEMENT AND WAIVER
Except as provided in the next two succeeding paragraphs, the Indenture,
the Notes or the Subsidiary Guarantees may be amended or supplemented with the
consent of the Holders of at least a majority in principal amount of the Notes
then outstanding (including, without limitation, consents obtained in connection
with a purchase of, or tender offer or exchange offer for, Notes), and any
existing default or compliance with any provision of the Indenture or the Notes
may be waived with the consent of the Holders of a majority in principal amount
of the then outstanding Notes (including consents obtained in connection with a
tender offer or exchange offer for Notes).
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Without the consent of each Holder affected, an amendment or waiver may not
(with respect to any Notes held by a non-consenting Holder): (i) reduce the
principal amount of Notes whose Holders must consent to an amendment, supplement
or waiver, (ii) reduce the principal of or change the fixed maturity of any Note
or alter the provisions with respect to the redemption of the Notes (other than
provisions relating to the covenants described above under the caption
"-- Repurchase at the Option of Holders"), (iii) reduce the rate of or change
the time for payment of interest or Liquidated Damages on any Note, (iv) waive a
Default or Event of Default in the payment of principal of or premium, if any,
or interest or Liquidated Damages, if any, on the Notes (except a rescission of
acceleration of the Notes by the Holders of at least a majority in aggregate
principal amount of the Notes and a waiver of the payment default that resulted
from such acceleration), (v) make any Note payable in money other than that
stated in the Notes, (vi) make any change in the provisions of the Indenture
relating to waivers of past Defaults or the rights of Holders of Notes to
receive payments of principal of or premium, if any, or interest or Liquidated
Damages, if any, on the Notes, (vii) waive a redemption payment with respect to
any Note (other than a payment required by one of the covenants described above
under the caption "-- Repurchase at the Option of Holders") or (viii) make any
change in the foregoing amendment and waiver provisions. In addition, any
amendment to certain provisions of the Indenture which relate to subordination
will require the consent of the Holders of at least 75% in aggregate principal
amount of the Notes then outstanding if such amendment would adversely affect
the rights of Holders of Notes.
Notwithstanding the foregoing, without the consent of any Holder of Notes,
the Company and the Trustee may amend or supplement the Indenture, the Notes or
the Subsidiary Guarantees to cure any ambiguity, defect or inconsistency, to
provide for uncertificated Notes in addition to or in place of certificated
Notes, to provide for the assumption of the Company's obligations to Holders of
Notes in the case of a merger or consolidation, to make any change that would
provide any additional rights or benefits to the Holders of Notes or that does
not adversely affect the legal rights under the Indenture of any such Holder, or
to comply with requirements of the Commission in order to effect or maintain the
qualification of the Indenture under the Trust Indenture Act or to add any
additional Guarantor or to release any Guarantor form its Subsidiary Guarantee,
in each case, as provided in the Indenture.
CONCERNING THE TRUSTEE
The Indenture contains certain limitations on the rights of the Trustee,
should it become a creditor of the Company, to obtain payment of claims in
certain cases, or to realize on certain property received in respect of any such
claim as security or otherwise. The Trustee will be permitted to engage in other
transactions; however, if it acquires any conflicting interest it must eliminate
such conflict within 90 days, apply to the Commission for permission to continue
or resign.
The Holders of a majority in principal amount of the then outstanding Notes
will have the right to direct the time, method and place of conducting any
proceeding for exercising any remedy available to the Trustee, subject to
certain exceptions. The Indenture provides that in case an Event of Default
shall occur and be continuing, the Trustee will be required, in the exercise of
its power, to use the degree of care of a prudent man in the conduct of his own
affairs. Subject to such provisions, the Trustee will be under no obligation to
exercise any of its rights or powers under the Indenture at the request of any
Holder of Notes, unless such Holder shall have offered to the Trustee security
and indemnity satisfactory to it against any loss, liability or expense.
ADDITIONAL INFORMATION
Anyone who receives this Prospectus may obtain a copy of the Indenture
without charge by writing to Tesoro Petroleum Corporation, 8700 Tesoro Drive,
San Antonio, Texas 78217-6218, Attention: Vice President, Finance and Treasurer.
BOOK-ENTRY, DELIVERY AND FORM
The Old Notes offered and sold to qualified institutional buyers
("Qualified Institutional Buyers" or "QIBs") are represented by one or more
global notes in registered, global form without interest coupons (collectively,
the "Rule 144A Global Note"). The Rule 144A Global Note was initially deposited
upon
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issuance with the Trustee as custodian for the Depositary, in New York, New
York, and registered in the name of the Depositary or its nominee, in each case
for credit to an account of a direct or indirect participant as described below.
The Old Notes offered and sold in offshore transactions in reliance on
Regulation S under the Securities Act initially are represented by one or more
temporary global notes in registered, global form without interest coupons
(collectively, the "Regulation S Temporary Global Note"). The Regulation S
Temporary Global Note was registered in the name of a nominee of the Depositary
for credit to the subscribers' respective accounts at the Euroclear System
("Euroclear") and Cedel Bank, S.A. ("CEDEL"). Beneficial interests in the
Regulation S Temporary Global Note may be held only through Euroclear or CEDEL.
Within a reasonable time period after the expiration of the period of 40
days commencing on the latest of the commencement of the Notes Offering and the
Issue Date of the Indenture of the Old Notes (such period through and including
such 40th day, the "Restricted Period"), the Regulation S Temporary Global Note
will be exchanged for one or more permanent global notes (collectively, the
"Regulation S Permanent Global Note" and, together with the Regulation S
Temporary Global Note, the "Regulation S Global Note" (the Regulation S Global
Note and the Rule 144A Global Note collectively being the "Global Old Notes"))
upon delivery to the Depositary of certification of compliance with the transfer
restrictions applicable to the Notes pursuant to Regulation S as provided in the
Indenture. During the Restricted Period, beneficial interests in the Regulation
S Temporary Global Note may be held only through Euroclear or CEDEL (as indirect
participants in the Depository). See "-- Depositary Procedures -- Exchanges
between Regulation S Notes and the Rule 144A Global Note." Beneficial interests
in the Rule 144A Global Note may not be exchanged for beneficial interests in
the Regulation S Global Note at any time except in the limited circumstances
described below. See "-- Depositary Procedures -- Exchanges between Regulation S
Notes and the Rule 144A Global Note."
The Exchange Notes also will be issued in the form of one or more Global
Notes (the "Global Exchange Notes" and, together with the Global Old Notes, the
"Global Notes"). The Global Exchange Notes will be deposited on the original
date of issuance of the Exchange Notes with, or on behalf of, DTC and registered
in the name of a nominee of the Depositary.
Except as set forth below, the Global Notes may be transferred, in whole
and not in part, only to another nominee of the Depositary or to a successor of
the Depositary or its nominee. Beneficial interests in the Global Notes may not
be exchanged for Notes in certificated form except in the limited circumstances
described below. See "-- Depositary Procedures -- Exchange of Book-Entry Notes
for Certificated Notes."
The Rule 144A Global Note (including beneficial interests in the Rule 144A
Global Note) is subject to certain restrictions on transfer and bears a
restrictive legend as described under "Notice to Investors." In addition,
transfer of beneficial interests in the Global Notes will be subject to the
applicable rules and procedures of the Depositary and its direct or indirect
participants (including, if applicable, those of Euroclear and CEDEL), which may
change from time to time.
The Notes may be presented for registration of transfer and exchange at the
offices of the Registrar.
DEPOSITARY PROCEDURES
The Depositary has advised the Company that the Depositary is a
limited-purpose trust company created to hold securities for its participating
organizations (collectively, the "Participants") and to facilitate the clearance
and settlement of transactions in those securities between Participants through
electronic book-entry changes in accounts of Participants. The Participants
include securities brokers and dealers (including the Initial Purchasers),
banks, trust companies, clearing corporations and certain other organizations.
Access to the Depositary's system is also available to other entities such as
banks, brokers, dealers and trust companies that clear through or maintain a
custodial relationship with a Participant, either directly or indirectly
(collectively, "Indirect Participants"). Persons who are not Participants may
beneficially own securities held by or on behalf of the Depositary only through
the Participants or Indirect Participants. The ownership interest
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and transfer of ownership interest of each actual purchaser of each security
held by or on behalf of the Depositary are recorded on the records of the
Participants and Indirect Participants.
The Depositary has also advised the Company that pursuant to procedures
established by it, (i) upon deposit of the Global Notes, the Depositary will
credit the accounts of Participants designated by the Initial Purchasers with
portions of the principal amount of Global Notes and (ii) ownership of such
interests in the Global Notes will be shown on, and the transfer of ownership
thereof will be effected only through, records maintained by the Depositary
(with respect to Participants) or by Participants and the Indirect Participants
(with respect to other owners of beneficial interests in the Global Notes).
Investors in the Rule 144A Global Note may hold their interests therein
directly through the Depositary, if they are Participants in such system, or
indirectly through organizations (including Euroclear and CEDEL) that are
Participants in such system. Investors in the Regulation S Global Note must
initially hold their interests therein through Euroclear or CEDEL, if they are
Participants in such systems, or indirectly through organizations that are
Participants in such systems. After the expiration of the Restricted Period (but
not earlier), investors may also hold interests in the Regulation S Global Note
through organizations other than Euroclear and CEDEL that are Participants in
the Depositary system. Euroclear and CEDEL will hold interests in the Regulation
S Global Note on behalf of their Participants through customers' securities
accounts in their respective names on the books of their respective
depositories, which are Morgan Guaranty Trust Company of New York, Brussels
office, as operator of Euroclear, and Citibank, N.A. as operator of CEDEL. The
depositories, in turn, will hold such interests in the Regulations S Global Note
in customers' securities accounts in the depositories' names on the books of the
Depositary. All interests in a Global Note, including those held through
Euroclear or CEDEL, may be subject to the procedures and requirements of the
Depositary. Those interests held by Euroclear or CEDEL may also be subject to
the procedures and requirements of such system.
The laws of some states require that certain persons take physical delivery
in definitive form of securities that they own. Consequently, the ability to
transfer beneficial interest in a Global Note to such persons may be limited to
that extent. Because the Depositary can act only on behalf of Participants,
which in turn act on behalf of Indirect Participants and certain banks, the
ability of a person having a beneficial interest in a Global Note to pledge such
interest to persons or entities that do not participate in the Depositary
system, or otherwise take actions in respect of such interests, may be affected
by the lack of physical certificate evidencing such interest. For certain other
restrictions on the transferability of the Notes, see "-- Exchange of Book-Entry
Notes for Certificated Notes" and "-- Exchanges between Regulation S Notes and
the Rule 144A Global Note."
EXCEPT AS DESCRIBED BELOW, OWNERS OF INTERESTS IN THE GLOBAL NOTES WILL NOT
HAVE NOTES REGISTERED IN THEIR NAMES, WILL NOT RECEIVE PHYSICAL DELIVERY OF
NOTES IN CERTIFICATED FORM AND WILL NOT BE CONSIDERED THE REGISTERED OWNERS, OR
HOLDERS THEREOF UNDER THE INDENTURE FOR ANY PURPOSE.
Payments in respect of the principal and premium and Liquidated Damages, if
any, and interest on a Global Note registered in the name of the Depositary or
its nominee will be payable by the Trustee to the Depositary or its nominee in
its capacity as the registered Holder under the Indenture. Under the terms of
the Indenture, the Company and the Trustee will treat the persons in whose names
the Notes, including the Global Notes, are registered as the owners thereof for
the purpose of receiving such payments and for any and all other purposes
whatsoever. Consequently, neither the Company, the Trustee nor any agent of the
Company or the Trustee has or will have any responsibility or liability for (i)
any aspect of the Depositary's records or any Participant's or Indirect
Participant's records relating to or payments made on account of beneficial
ownership interests in the Global Notes, or for maintaining, supervising or
reviewing any of the Depositary's records or any Participant's or Indirect
Participant's records relating to the beneficial ownership interests in the
Global Notes or (ii) any other matter relating to the actions and practices of
the Depositary or any of its Participants or Indirect Participants.
The Depositary has advised the Company that its current practices, upon
receipt of any payment in respect of securities such as the Notes (including
principal and interest and Liquidated Damages, if any), is to credit the
accounts of the relevant Participants with the payment on the payment date, in
amounts
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proportionate to their respective holdings in principal amount of beneficial
interests in the relevant security such as the Global Notes as shown on the
records of the Depositary. Payments by Participants and the Indirect
Participants to the beneficial owners of Notes will be governed by standing
instructions and customary practices and will not be the responsibility of the
Depositary, the Trustee or the Company. Neither the Company nor the Trustee will
be liable for any delay by the Depositary or its Participants in identifying the
beneficial owners of the Notes, and the Company and the Trustee may conclusively
rely on and will be protected in relying on instructions from the Depositary or
its nominee as the registered owner of the Notes for all purposes.
Except for trades involving only Euroclear and CEDEL Participants,
interests in the Global Notes will trade in the Depositary's Same-Day Funds
Settlement System and secondary market trading activity in such interests will,
therefore, settle in immediately available funds, subject in all cases to the
rules and procedures of the Depositary and its Participants.
Transfers between Participants in the Depositary will be effective in
accordance with the Depositary's procedures, and will be settled in same-day
funds. Transfers between Participants in Euroclear and CEDEL will be effected in
the ordinary way in accordance with their respective rules and operating
procedures.
Subject to compliance with the transfer restrictions applicable to the
Notes described herein, cross-market transfers between Participants in the
Depositary, on the one hand, and Euroclear or CEDEL Participants, on the other
hand, will be effected through the Depositary in accordance with the
depository's rules on behalf of Euroclear or CEDEL, as the case may be, by its
respective depository; however, such cross-market transactions will require
delivery of instructions to Euroclear or CEDEL, as the case may be, by the
counterparty in such system in accordance with the rules and procedures and
within the established deadlines (Brussels time) of such system. Euroclear or
CEDEL, as the case may be, will, if the transaction meets its settlement
requirements, deliver instructions to its respective depository to take action
to effect final settlement on its behalf by delivering or receiving interests in
the relevant Global Note in the Depositary, and making or receiving payment in
accordance with normal procedures for same-day fund settlement applicable to the
Depositary. Euroclear Participants and CEDEL Participants may not deliver
instructions directly to the depositories for Euroclear or CEDEL.
Due to time zone differences, the securities accounts of a Euroclear or
CEDEL Participant purchasing an interest in a Global Note from a Participant in
the Depositary will be credited, and any such crediting will be reported to the
relevant Euroclear or CEDEL Participant, during the securities settlement
processing day (which must be a business day for Euroclear or CEDEL) immediately
following the settlement date of the Depositary. Cash received in Euroclear or
CEDEL as a result of sales of interests in a Global Note by or through a
Euroclear or CEDEL Participant to a Participant in the Depositary will be
received with value on the settlement date of the Depositary but will be
available in the relevant Euroclear or CEDEL cash account only as of the
business day for Euroclear or CEDEL following the Depositary's settlement date.
The Depositary has advised the Company that it will take any action
permitted to be taken by a Holder of Notes only at the direction of one or more
Participants to whose account the Depositary interests in the Global Notes are
credited and only in respect of such portion of the aggregate principal amount
of the Notes as to which such Participant or Participants has or have given
direction. However, if there is an Event of Default under the Notes, the
Depositary reserves the right to exchange Global Notes for legend Notes in
certificated form, and to distribute such Notes to its Participants.
The information in this section concerning the Depositary, Euroclear and
CEDEL and their book-entry systems has been obtained from sources that the
Company believes to be reliable, but the Company takes no responsibility for the
accuracy thereof.
Although the Depositary, Euroclear and CEDEL have agreed to the foregoing
procedures to facilitate transfers of interests in the Regulation S Global Note
and in the Rule 144A Global Note among Participants in the Depositary, Euroclear
and CEDEL, they are under no obligation to perform or to continue to perform
such procedures, and such procedures may be discontinued at any time. None of
the Company, the Initial Purchasers or the Trustee will have any responsibility
for the performance by the Depositary, Euroclear or
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CEDEL or their respective Participants or Indirect Participants of their
respective obligations under the rules and procedures governing their
operations.
Exchange of Book-Entry Notes for Certificated Notes. A Global Note is
exchangeable for definitive Notes in registered certificated form if (i) the
Depositary (A) notifies the Company that it is unwilling or unable to continue
as depository for the Global Note and the Company thereupon fails to appoint a
successor depository or (B) has ceased to be a clearing agency registered under
the Exchange Act or (ii) the Company, at its option, notifies the Trustee in
writing that it elects to cause issuance of the Notes in certificated form. In
addition, beneficial interests in a Global Note may be exchanged for
certificated Notes upon request but only upon at least 20 days prior written
notice given to the Trustee by or on behalf of the Depositary in accordance with
customary procedures. In all cases, certificated Notes delivered in exchange for
any Global Note or beneficial interest therein will be registered in names, and
issued in any approved denominations, requested by or on behalf of the
Depositary (in accordance with its customary procedures) and will bear, in the
case of the Rule 144A Global Note, the restrictive legend referred to in "Notice
to Investors" and, in the case of the Regulation S Global Note, the legend set
forth in bold type on the cover of this Prospectus, in each case, unless the
Company determines otherwise in compliance with applicable law.
Exchanges between Regulation S Notes and the Rule 144A Global Note. Prior
to the expiration of the Restricted Period, a beneficial interest in a
Regulation S Global Note may not be transferred to a U.S. person. Thereafter,
such transfers will be permitted on the terms specified in the Indenture.
Beneficial interests in Rule 144A Global Notes may be transferred to a
person who takes delivery in the form of an interest in Regulation S Global
Notes, whether before or after the expiration of the Restricted Period, only if
the transferor first delivers to the Trustee a written certificate to the effect
that such transfer is being made in accordance with Rule 903 or 904 of
Regulation S and that, if such transfer occurs prior to the expiration of the
Restricted Period, the interest transferred will be held immediately thereafter
through Euroclear and CEDEL.
Any beneficial interest in one of the Old Global Notes that is transferred
to a person who takes delivery in the form of an interest in another Old Global
Note will, upon transfer, cease to be an interest in such Old Global Note and
become an interest in such other Old Global Note, and accordingly, will
thereafter be subject to all transfer restrictions and other procedures
applicable to beneficial interests in such other Old Global Note for as long as
it remains such an interest.
Transfers involving an exchange of a beneficial interest in the Regulation
S Global Note for a beneficial interest in the Rule 144A Global Note or vice
versa will be effected by the Depositary by means of an instruction originated
by the Trustee through the Depositary/Deposit Withdraw at Custodian system.
Accordingly, in connection with such transfer, appropriate adjustments will be
made to reflect a decrease in the principal amount of the Regulation S Global
Note and a corresponding increase in the principal amount of the Rule 144A
Global Note or vice versa, as applicable.
Certificated Notes. Subject to certain conditions, any person having a
beneficial interest in the Global Note may, upon request to the Trustee,
exchange such beneficial interest for Notes in the form of certificated Notes.
Upon any such issuance, the Trustee is required to register such certificated
Notes in the name of, and cause the same to be delivered to, such person or
persons (or the nominee of any thereof). All such certificated Notes would be
subject to the legend requirements described herein under "Notice to Investors."
In addition, if (i) the Company notifies the Trustee in writing that the
Depositary is no longer willing or able to act as a depository and the Company
is unable to locate a qualified successor within 90 days or (ii) the Company, at
its option, notifies the Trustee in writing that it elects to cause the issuance
of Notes in the form of certificated Notes under the Indenture, then, upon
surrender by the Global Note Holder of its Global Note, Notes in such form will
be issued to each person that the Global Note Holder and the Depositary identify
as being the beneficial owner of the related Notes.
Neither the Company nor the Trustee will be liable for any delay by the
Global Note Holder or the Depositary in identifying the beneficial owners of
Notes and the Company and the Trustee may conclusively
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rely on, and will be protected in relying on, instructions from the Global Note
Holder or the Depositary for all purposes.
Same Day Settlement and Payment. The Indenture will require that payments
in respect of the Notes represented by the Global Note (including principal,
premium, if any, interest and Liquidated Damages, if any) be made by wire
transfer of immediately available funds to the accounts specified by the Global
Note Holder. With respect to certificated Notes, the Company will make all
payments of principal, premium, if any, interest and Liquidated Damages, if any,
by wire transfer of immediately available funds to the accounts specified by the
Holders thereof or, if no such account is specified, by mailing a check to each
such Holder's registered address. The Company expects that secondary trading in
the certificated Notes will also be settled in immediately available funds.
REGISTRATION RIGHTS; LIQUIDATED DAMAGES
Pursuant to the Registration Rights Agreement, the Company has agreed to
file with the Commission this Exchange Offer Registration Statement under the
Securities Act with respect to the Exchange Notes. Upon the effectiveness of the
Exchange Offer Registration Statement, the Company will offer pursuant to the
Exchange Offer to the Holders of Transfer Restricted Securities who are able to
make certain representations the opportunity to exchange their Transfer
Restricted Securities for Exchange Notes. If (i) the Company is not required to
file the Exchange Offer Registration Statement or permitted to consummate the
Exchange Offer because the Exchange Offer is not permitted by applicable law or
Commission policy or (ii) any Holder of Transfer Restricted Securities notifies
the Company within 20 business days following consummation of the Exchange Offer
that (A) it is prohibited by law or Commission policy from participating in the
Exchange Offer or (B) it may not resell the Exchange Notes acquired by it in the
Exchange Offer to the public without delivering a prospectus and the prospectus
contained in the Exchange Offer Registration Statement is not appropriate or
available for such resales or (C) that it is a broker-dealer and owns Notes
acquired directly from the Company or an affiliate of the Company, the Company
will file with the Commission a Shelf Registration Statement to cover resales of
the Notes by the Holders thereof who satisfy certain conditions relating to the
provision of information in connection with the Shelf Registration Statement.
The Company will use its best efforts to cause the applicable registration
statement to be declared effective as promptly as possible by the Commission.
For purposes of the foregoing, "Transfer Restricted Securities" means each Note
until (i) the date on which such Note has been exchanged by a person other than
a broker-dealer for a Exchange Note in the Exchange Offer, (ii) following the
exchange by a broker-dealer in the Exchange Offer of a Note for a Exchange Note,
the date on which such Exchange Note is sold to a purchaser who receives from
such broker-dealer on or prior to the date of such sale a copy of the prospectus
contained in the Exchange Offer Registration Statement, (iii) the date on which
such Note has been effectively registered under the Securities Act and disposed
of in accordance with the Shelf Registration Statement or (iv) the date on which
such Note is distributed to the public pursuant to Rule 144 under the Securities
Act.
The Registration Rights Agreement provides that (i) the Company will file
an Exchange Offer Registration Statement with the Commission on or prior to 60
days after the Closing Date, (ii) the Company will use its best efforts to have
the Exchange Offer Registration Statement declared effective by the Commission
on or prior to 120 days after the Closing Date, (iii) unless the Exchange Offer
would not be permitted by applicable law or Commission policy, the Company will
commence the Exchange Offer and use its best efforts to issue on or prior to 30
business days after the date on which the Exchange Offer Registration Statement
was declared effective by the Commission, Exchange Notes in exchange for all
Notes tendered prior thereto in the Exchange Offer and (iv) if obligated to file
the Shelf Registration Statement, the Company will use its best efforts to file
the Shelf Registration Statement with the Commission on or prior to 60 days
after such filing obligation arises (and in any event within 120 days after the
Closing Date) and to cause the Shelf Registration to be declared effective by
the Commission on or prior to 60 days after the date upon which the Company is
obligated to make such filing. If (a) the Company fails to file any of the
Registration Statements required by the Registration Rights Agreement on or
before the date specified for such filing, (b) any of such Registration
Statements is not declared effective by the Commission on or prior to the date
specified for such effectiveness (the "Effectiveness Target Date"), or (c) the
Company fails to
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consummate the Exchange Offer within 30 business days of the Effectiveness
Target Date with respect to the Exchange Offer Registration Statement, or (d)
the Shelf Registration Statement or the Exchange Offer Registration Statement is
declared effective but thereafter ceases to be effective or usable in connection
with resales of Transfer Restricted Securities during the periods specified in
the Registration Rights Agreement (each such event referred to in clauses (a)
through (d) above a "Registration Default"), then the Company will pay
Liquidated Damages to each Holder of Notes, with respect to the first 90-day
period immediately following the occurrence of such Registration Default in an
amount equal to $0.05 per week per $1,000 principal amount of Notes held by such
Holder. The amount of the Liquidated Damages will increase by an additional
$0.05 per week per $1,000 principal amount of Notes with respect to each
subsequent 90-day period until all Registration Defaults have been cured, up to
a maximum amount of Liquidated Damages of $0.50 per week per $1,000 principal
amount of Notes. All accrued Liquidated Damages will be paid by the Company on
each Damages Payment Date to the Global Note Holder by wire transfer of
immediately available funds or by federal funds check and to Holders of
Certificated Securities by wire transfer to the accounts specified by them or by
mailing checks to their registered addresses if no such accounts have been
specified. Following the cure of all Registration Defaults, the accrual of
Liquidated Damages will cease.
Holders of Notes will be required to make certain representations to the
Company (as described in the Registration Rights Agreement) in order to
participate in the Exchange Offer and will be required to deliver information to
be used in connection with the Shelf Registration Statement and to provide
comments on the Shelf Registration Statement within the time periods set forth
in the Registration Rights Agreement in order to have their Notes included in
the Shelf Registration Statement and benefit from the provisions regarding
Liquidated Damages set forth above.
Holders of the 10 1/4% Notes will not be entitled to certain rights under
the Registration Rights Agreement following the consummation of the Exchange
Offer. The rights that will terminate are the right (i) to have the Company file
with the Commission and use its best efforts to have declared effective a shelf
registration statement to cover resales of the Old Notes by the holders thereof
and (ii) to receive additional interest if the registration statement of which
this Prospectus is a part or the shelf registration statement are not filed
with, or declared effective by, the Commission within certain specified time
periods or the Exchange Offer is not consummated within a specified time period.
CERTAIN DEFINITIONS
Set forth below are certain defined terms used in the Indenture. Reference
is made to the Indenture for a full disclosure of all such terms, as well as any
other capitalized terms used herein for which no definition is provided.
"Acquired Debt" means, with respect to any specified Person, (i)
Indebtedness of any other Person existing at the time such other Person is
merged with or into or became a Restricted Subsidiary of such specified Person,
including, without limitation, Indebtedness incurred in connection with, or in
contemplation of, such other Person merging with or into or becoming a
Restricted Subsidiary of such specified Person, and (ii) Indebtedness secured by
a Lien encumbering any asset acquired by such specified Person.
"Affiliate" of any specified Person means any other Person directly or
indirectly controlling or controlled by or under direct or indirect common
control with such specified Person. For purposes of this definition, "control"
(including, with correlative meanings, the terms "controlling," "controlled by"
and "under common control with"), as used with respect to any Person, shall mean
the possession, directly or indirectly, of the power to direct or cause the
direction of the management or policies of such Person, whether through the
ownership of voting securities, by agreement or otherwise; provided that, for
purposes of the covenant described under the caption "-- Certain
Covenants -- Transactions with Affiliates" and the use of the term "Affiliates"
thereunder, beneficial ownership of 10% or more of the voting securities of a
Person shall be deemed to be control.
"Asset Sale" means (i) the sale, lease, conveyance or other disposition of
any assets or rights (including, without limitation, by way of a sale and
leaseback) other than in the ordinary course of business (provided that the
sale, lease, conveyance or other disposition of all or substantially all of the
assets of the Company and
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its Restricted Subsidiaries taken as a whole will be governed by the covenants
described above under the captions "-- Repurchase at the Option of
Holders -- Change of Control" and "-- Certain Covenants -- Merger,
Consolidation, or Sale of Assets" and not by the provisions of the covenant
described above under the caption "-- Repurchase at the Option of
Holders -- Asset Sales"), and (ii) the issue or sale by the Company or any of
its Restricted Subsidiaries of Equity Interests of any of the Company's
Restricted Subsidiaries, in the case of either clause (i) or (ii), whether in a
single transaction or a series of related transactions, (a) that have a Fair
Market Value in excess of $2 million or (b) for Net Proceeds in excess of $2
million; provided that the following will not be deemed to be Asset Sales: (i)
any transfer, conveyance, sale, lease or other disposition of assets or rights
securing the Senior Credit Facility or other Senior Debt in connection with the
enforcement of the Liens therein; (ii) any sale or exchange of production of
crude oil, natural gas and natural gas liquids, or refined products or residual
hydrocarbons, or any other asset or right constituting inventory, made in the
ordinary course of the Permitted Business; (iii) any disposition of assets in
trade or exchange for assets of comparable Fair Market Value used or usable in
any Permitted Business (including, without limitation, the trade or exchange for
a controlling interest in another business or all or substantially all of the
assets of a business, in each case engaged in a Permitted Business or for other
non-current assets to be used in a Permitted Business, including, without
limitation, assets or Investments of the nature or type described in clause (m)
of the definition of "Permitted Investments"), provided that (x) except for
trades or exchanges of oil and gas properties and interests therein for other
oil and gas properties and interests therein, if the Fair Market Value of the
assets so disposed of, in a single transaction or in a series of related
transactions, is in excess of $20 million, the Company shall obtain an opinion
or report from a Independent Financial Advisor confirming that the assets
received by the Company and the Restricted Subsidiaries in such trade or
exchange have a fair market value of at least the fair market value of the
assets so disposed and (y) any cash or Cash Equivalent received by the Company
or a Restricted Subsidiary in connection with such trade or exchange (net of any
transaction costs of the type deducted under the definition of "Net Proceeds")
shall be treated as Net Proceeds of an Asset Sale and shall be applied in the
manner set forth in the covenant described under the caption "-- Repurchase at
the Option of Holders -- Asset Sales"; (iv) a transfer of assets by the Company
to a Restricted Subsidiary of the Company or by a Restricted Subsidiary of the
Company to the Company or to a Restricted Subsidiary of the Company; (v) an
issuance or sale of Equity Interests by a Restricted Subsidiary of the Company
to the Company or to another Restricted Subsidiary of the Company; (vii) (A) a
Permitted Investment or (B) a Restricted Payment that is permitted by the
covenant described above under the caption "Certain Covenants -- Restricted
Payments"; (viii) the trade, sale or exchange of Cash Equivalents; (ix) the
sale, exchange or other disposition of obsolete assets not integral to any
Permitted Business; (x) the abandonment or relinquishment of assets or property
in the ordinary course of business, including without limitation the
abandonment, relinquishment or farm-out of oil and gas leases, concessions or
drilling or exploration rights or interests therein; (xi) any lease of assets
entered into in the ordinary course of business and with respect to which the
Company or any Restricted Subsidiary of the Company is the lessor and the lessee
has no option to purchase such assets for less than fair market value at any
time the right to acquire such asset occurs; (x) the disposition of assets
received in settlement of debts accrued in the ordinary course of business; and
(xi) any Production Payment created, incurred, issued, assumed or guaranteed in
connection with the financing of, and within 30 days after the acquisition of,
the oil and gas property that is subject thereto.
"BHP Note" means that certain unsecured, non-interest bearing promissory
note dated May 29, 1998 issued by the Company in the principal amount of $50
million to BHP Hawaii Inc.
"Board of Directors" means the Board of Directors of the Company or any
committee thereof duly authorized to act on behalf of such Board.
"Capital Lease Obligation" means, at the time any determination thereof is
to be made, the amount of the liability in respect of a capital lease that would
at such time be required to be capitalized on a balance sheet in accordance with
GAAP.
"Capital Stock" means (i) in the case of a corporation, corporate stock,
(ii) in the case of an association or business entity, any and all shares,
interests, participation, rights or other equivalents (however designated) of
corporate stock, (iii) in the case of a partnership or limited liability
company, partnership or membership
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interests (whether general or limited) and (iv) any other interest or
participation that confers on a Person the right to receive a share of the
profits and losses of, or distributions of assets of, the issuing Person.
"Cash Equivalents" means (i) United States dollars, (ii) securities issued
or directly and fully guaranteed or insured by the United States government or
any agency or instrumentality thereof having maturities of not more than one
year from the date of acquisition, (iii) certificates of deposit and Eurodollar
time deposits with maturities of not more than one year from the date of
acquisition, bankers' acceptances with maturities of not more than one year from
the date of acquisition and overnight bank deposits, in each case with any
domestic commercial bank having capital and surplus in excess of $500.0 million
and a Thompson Bank Watch Rating of "B" or better, (iv) repurchase obligations
with a term of not more than seven days for underlying securities of the types
described in clauses (ii) and (iii) above entered into with any financial
institution meeting the qualifications specified in clause (iii) above and (v)
commercial paper having the highest rating obtainable from Moody's Investors
Service, Inc. or Standard & Poor's Rating Group with maturities of not more than
one year from the date of acquisition.
"Change of Control" means the occurrence of one or more of the following
events: (i) any sale, lease, exchange or other transfer (in one transaction or a
series of related transactions) of all or substantially all of the assets of the
Company to any Person or group of related Persons for purposes of Section 13(d)
of the Exchange Act (a "Group") together with any Affiliates thereof (whether or
not otherwise in compliance with the provisions of the Indenture) unless
immediately following such sale, lease, exchange or other transfer in compliance
with the Indenture such assets are owned, directly or indirectly, by the Company
or a Wholly Owned Subsidiary of the Company; (ii) the approval by the holders of
Capital Stock of the Company of any plan or proposal for the liquidation or
dissolution of the Company; (iii) the acquisition in one or more transactions,
of beneficial ownership (within the meaning of Rule 13d-3 under the Exchange
Act) of Voting Securities of the Company by any Person or Group that either (A)
beneficially owns (within the meaning of Rule 13d-3 under the Exchange Act),
directly or indirectly, at least 50% of the Company's then outstanding voting
securities entitled to vote on a regular basis for the board of directors of the
Company, or (B) otherwise has the ability to elect, directly or indirectly, a
majority of the members of the Company's board of directors, including, without
limitation, by the acquisition of revocable proxies for the election of
directors; or (iv) during any period of two consecutive years, individuals who
at the beginning of such period constituted the board of directors of the
Company (together with any new directors whose election by such board of
directors or whose nomination for election by the shareholders (or members, as
applicable) of the Company was approved by a vote of 66 2/3% of the directors of
the Company then still in office who were either directors at the beginning of
such period or whose election or nomination for election was previously so
approved) cease for any reason to constitute a majority of the board of
directors then in office.
"Commodity Hedging Agreements" means agreements or arrangements designed to
protect such Person against fluctuations in the price of (i) crude oil, natural
gas, or other hydrocarbons, including refined hydrocarbon products or (ii)
electricity and other sources of energy or power used in the Company's refining,
processing or exploration and production operations, in either case in
connection with the conduct of its business and not for speculative purposes.
"Commodity Hedging Obligations" means, with respect to any Person, the net
payment Obligations of such Person under Commodity Hedge Agreements.
"Consolidated Cash Flow" means, with respect to any Person for any period,
the Consolidated Net Income of such Person for such period plus (i) an amount
equal to any extraordinary, unusual or non-recurring expenses or losses
(including, whether or not otherwise includable as a separate item in the
statement of Consolidated Net Income for such period, losses on sales of assets
outside of the ordinary course of business) plus any net loss realized in
connection with an Asset Sale (to the extent such losses were deducted in
computing such Consolidated Net Income), plus (ii) provision for taxes based on
income or profits of such Person and its Restricted Subsidiaries for such
period, to the extent that such provision for taxes was included in computing
such Consolidated Net Income, plus (iii) consolidated interest expense of such
Person and its Restricted Subsidiaries for such period, whether paid or accrued
and whether or not capitalized (including, without limitation, amortization of
debt issuance costs and original issue discount, non-cash
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interest payments, the interest component of any deferred payment obligations,
the interest component of all payments associated with Capital Lease
Obligations, commissions, discounts and other fees and charges incurred in
respect of letter of credit or bankers' acceptance financings, and net payments
(if any) pursuant to Hedging Obligations), to the extent that any such expense
was deducted in computing such Consolidated Net Income, plus (iv) depreciation
and amortization (including amortization of goodwill and other intangibles but
excluding amortization of prepaid cash expenses that were paid in a prior
period) of such Person and its Restricted Subsidiaries for such period to the
extent that such depreciation and amortization were deducted in computing such
Consolidated Net Income, minus (v) non-cash items increasing such Consolidated
Net Income for such period, in each case, on a consolidated basis and determined
in accordance with GAAP. Notwithstanding the foregoing, the provision for taxes
on the income or profits of, and the depreciation and amortization and other
non-cash charges of, a Restricted Subsidiary of the referent Person shall be
added to Consolidated Net Income to compute Consolidated Cash Flow only to the
extent (and in same proportion) that the Net Income of such Restricted
Subsidiary was included in calculating the Consolidated Net Income of such
Person and only if a corresponding amount would be permitted at the date of
determination to be dividended to the Company by such Restricted Subsidiary
without prior governmental approval (that has not been obtained), and without
direct or indirect restriction pursuant to the terms of its charter and all
agreements, instruments, judgments, decrees, orders, statutes, rules and
governmental regulations applicable to that Restricted Subsidiary or its
stockholders.
"Consolidated Net Income" means, with respect to any Person for any period,
the aggregate of the Net Income of such Person and its Restricted Subsidiaries
(for such period, on a consolidated basis, determined in accordance with GAAP);
provided that (i) the Net Income (but not loss) of any Person that is not a
Restricted Subsidiary or that is accounted for by the equity method of
accounting shall be included only to the extent of the amount of dividends or
distributions paid in cash to the referent Person or a Restricted Subsidiary,
(ii) the Net Income of any Restricted Subsidiary shall be excluded to the extent
that the declaration or payment of dividends or similar distributions by that
Restricted Subsidiary of that Net Income is not at the date of determination
permitted without any prior governmental approval (that has not been obtained)
or, directly or indirectly, by operation of the terms of its charter or any
agreement, instrument, judgment, decree, order, statute, rule or governmental
regulation applicable to that Restricted Subsidiary or its stockholders, (iii)
the Net Income of any Person acquired in a pooling of interests transaction for
any period prior to the date of such acquisition shall be excluded, (iv) the
cumulative effect of a change in accounting principles shall be excluded and (v)
any ceiling limitation writedowns under Securities and Exchange Commission
guidelines shall be treated as capitalized costs, as if such writedown had not
occurred.
"Consolidated Net Worth" means, with respect to any Person as of any date,
the sum of (i) the consolidated equity of the common stockholders of such Person
and its consolidated Restricted Subsidiaries as of such date plus (ii) the
respective amounts reported on such Person's balance sheet as of such date with
respect to any series of preferred stock (other than Disqualified Stock) that by
its terms is not entitled to the payment of dividends unless such dividends may
be declared and paid only out of net earnings in respect of the year of such
declaration and payment, but only to the extent of any cash received by such
Person upon issuance of such preferred stock, all of the foregoing determined in
accordance with GAAP.
"Credit Facility" means, with respect to the Company or any Restricted
Subsidiary, one or more debt facilities (including, without limitation, the
Senior Credit Facility) or commercial paper facilities with banks or other
institutional lenders providing for revolving credit loans, other borrowings
(including term loans), receivables financing (including through the sale of
receivables to such lenders or to special purpose entities formed to borrow from
such lenders against such receivables) or letters of credit, in each case, as
amended, restated, modified, renewed, extended, refunded, replaced or refinanced
(in each case, without limitation as to amount) in whole or in part from time to
time.
"Default" means any event that is or with the passage of time or the giving
of notice (or both) would be an Event of Default.
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"Designated Senior Debt" means (i) any Indebtedness outstanding under the
Senior Credit Facility and (ii) any other Senior Debt permitted hereunder the
principal amount of which is $25 million or more and that has been designated by
the Company as "Designated Senior Debt."
"Disqualified Stock" means, with respect to any Person, any Capital Stock
to the extent that by its terms (or by the terms of any security into which it
is convertible or for which it is exchangeable) or upon the happening of any
event, it matures or is mandatorily redeemable pursuant to a sinking fund
obligation or otherwise, or is redeemable at the option of the Holder thereof,
in whole or in part, on or prior to the date that is 91 days after the date on
which the Notes mature, except such Capital Stock that is solely redeemable
with, or solely exchangeable for, any Capital Stock of such Person that is not
Disqualified Stock.
"Dollar-Denominated Production Payments" means production payment
obligations recorded as liabilities in accordance with GAAP, together with all
undertakings and obligations in connection therewith.
"Equity Interests" means Capital Stock and all warrants, options or other
rights to acquire Capital Stock (but excluding any debt security that is
convertible into, or exchangeable for, Capital Stock).
"Exchange Notes" means notes designated as "Series B" in the Indenture and
registered under the Securities Act that are issued under the Indenture in
exchange for the Notes initially issued under the Indenture pursuant to the
Exchange Offer or in replacement of any such initially issued Notes pursuant to
the Shelf Registration Statement.
"Existing Indebtedness" means the BHP Note and up to an additional $25
million in aggregate amount of principal, letters of credit reimbursement
obligations or Capital Lease Obligation, of Indebtedness of the Company and its
Restricted Subsidiaries (other than Indebtedness under the Senior Credit
Facility and the Notes) in existence on the Issue Date.
"Fair Market Value" means, with respect to consideration received or to be
received, or given or to be given, pursuant to any transaction by the Company or
any Restricted Subsidiary, the fair market value of such consideration as
determined in good faith by the Board of Directors of the Company.
"Financial Hedging Obligations" means, with respect to any Person, the net
payment Obligations of such Person under (i) interest rate swap agreements,
interest rate cap agreements and interest rate collar agreements and (ii) other
agreements or arrangements designed to protect such Person against fluctuations
in interest rates or currency exchange rates in connection with the conduct of
its business and not for speculative purposes.
"Fixed Charges" means, with respect to any Person for any period, the sum,
without duplication, of (i) the consolidated interest expense of such Person and
its Restricted Subsidiaries for such period, whether paid or accrued (including,
without limitation or duplication, amortization of debt issuance costs and
original issue discount, non-cash interest payments, the interest component of
any deferred payment obligations, the interest component of all payments
associated with Capital Lease Obligations, commissions, discounts and other fees
and charges incurred in respect of letter of credit or bankers' acceptance
financings, and net payments (if any) pursuant to Hedging Obligations), (ii) the
consolidated interest of such Person and its Restricted Subsidiaries that was
capitalized during such period, (iii) any interest expense on Indebtedness of
another Person that is guaranteed by such Person or one of its Restricted
Subsidiaries or secured by a Lien on assets of such Person or one of its
Restricted Subsidiaries (whether or not such guarantee or Lien is called upon),
and (iv) the product of (a) all dividend payments, whether or not in cash, on
any series of preferred stock of such Person or any of its Restricted
Subsidiaries, other than dividend payments on Equity Interests payable solely in
Equity Interests of the Company (other than Disqualified Stock), times (b) a
fraction, the numerator of which is one and the denominator of which is one
minus the then current combined federal, state and local statutory tax rate of
such Person, expressed as a decimal, in each case, on a consolidated basis and
in accordance with GAAP; provided that interest attributable to
Dollar-Denominated Production Payments shall be excluded from Fixed Charges.
"Fixed Charge Coverage Ratio" means with respect to any Person for any
period, the ratio of the Consolidated Cash Flow of such Person for such period
to the Fixed Charges of such Person for such period.
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In the event that the Company or any of its Restricted Subsidiaries incurs,
assumes, guarantees or redeems any Indebtedness (other than revolving credit
borrowings under any Credit Facility) or issues or redeems preferred stock
subsequent to the commencement of the period for which the Fixed Charge Coverage
Ratio is being calculated but on or prior to the date on which the event for
which the calculation of the Fixed Charge Coverage Ratio is made (the
"Calculation Date"), then the Fixed Charge Coverage Ratio shall be calculated
giving pro forma effect to such incurrence, assumption, guarantee or redemption
of Indebtedness, or such issuance or redemption of preferred stock, as if the
same had occurred at the beginning of the applicable four-quarter reference
period. In addition, for purposes of making the computation referred to above,
(i) acquisitions that have been made by the Company or any of its Restricted
Subsidiaries, including through mergers or consolidations and including any
related financing transactions, during the four-quarter reference period or
subsequent to such reference period and on or prior to the Calculation Date
shall be deemed to have occurred on the first day of the four-quarter reference
period and Consolidated Cash Flow for such reference period shall be calculated
without giving effect to clause (iii) of the proviso set forth in the definition
of Consolidated Net Income, (ii) the Consolidated Cash Flow attributable to
discontinued operations, as determined in accordance with GAAP, and operations
or businesses disposed of prior to the Calculation Date, shall be excluded, and
(iii) the Fixed Charges attributable to discontinued operations, as determined
in accordance with GAAP, and operations or businesses disposed of prior to the
Calculation Date, shall be excluded, but only to the extent that the obligations
giving rise to such Fixed Charges will not be obligations of the referent Person
or any of its Restricted Subsidiaries following the Calculation Date.
"GAAP" means generally accepted accounting principles set forth in the
opinions and pronouncements of the Accounting Principles Board of the American
Institute of Certified Public Accountants, the statements and pronouncements of
the Financial Accounting Standards Board and such other statements by such other
entities as have been approved by a significant segment of the accounting
profession, which are applicable at the date of determination.
"Government Securities" means direct obligations of, or obligations
guaranteed by, the United States of America for the payment of which guarantees
or obligations the full faith and credit of the United States is pledged.
"guarantee" means a guarantee (other than by endorsement of negotiable
instruments for collection in the ordinary course of business), direct or
indirect, in any manner (including, without limitation, letters of credit and
reimbursement agreements in respect thereof or pledging assets to secure), of
all or any part of any Indebtedness.
"Guarantors" means (i) each of Tesoro Petroleum Companies, Inc., Digicomp
Inc., Tesoro Financial Services Holding Company, Victory Finance Company, Tesoro
Alaska Petroleum Company, Interior Fuels Company, Kenai Pipe Line Company,
Tesoro Alaska Pipeline Company, Tesoro Northstore Company, Tesoro Refining,
Marketing & Supply Company, Tesoro Vostok Company, Tesoro Exploration and
Production Company, Tesoro Gas Resources Company, Inc., Tesoro E&P Company,
L.P., Tesoro Natural Gas Company, Tesoro Pipeline Company, L.P., Tesoro Bolivia
Petroleum Company, Tesoro Latin America Company, Tesoro Marine Services Holding
Company, Tesoro Marine Services, Inc., Tesoro Hawaii Corporation (formerly known
as BHP Petroleum Americas Refining Inc.), and Tesoro South Pacific Petroleum
Company (formerly known as BHP Petroleum South Pacific Inc.), (ii) each of the
Company's Restricted Subsidiaries that becomes a guarantor of the Notes pursuant
to the covenant described above under "-- Certain Covenants -- Additional
Subsidiary Guarantees" and (iii) each of the Company's Restricted Subsidiaries
executing a supplemental indenture in which such Restricted Subsidiary agrees to
be bound by the terms of the Indenture; provided that any Person constituting a
Guarantor as described above shall cease to constitute a Guarantor when its
respective Subsidiary Guarantee is released in accordance with the terms
thereof.
"Hedging Obligations" means, with respect to any Person, collectively, the
Commodity Hedging Obligations of such Person and the Financial Hedging
Obligations of such Person.
"Indebtedness" means, with respect to any Person, without duplication, (i)
(A) the principal of and premium, if any, with respect to indebtedness of such
Person for borrowed money or evidenced by bonds, notes, debentures or similar
instruments, (B) reimbursement obligations of such Person for letters of credit
or
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banker's acceptances, (C) Capital Lease Obligations of such Person, (D)
obligations of such Person for the payment of the balance deferred and unpaid of
the purchase price of any property except any such balance that constitutes an
accrued expense or trade payable or (E) Hedging Obligations, in each case of the
foregoing subclauses (A) through (E) if and to the extent any of the foregoing
obligations or indebtedness (other than letters of credit and Hedging
Obligations) would appear as a liability upon a balance sheet of such Person
prepared in accordance with GAAP, (ii) obligations or indebtedness of others of
the type referred to in the subclauses (A) through (E) of the foregoing clause
(i) that are secured by a Lien on any asset of such Person (whether or not such
Indebtedness is assumed by such Person), but in an amount not to exceed the
lesser of the amount of such other Person's obligation or indebtedness or the
Fair Market Value of such asset, (iii) to the extent not otherwise included, the
guarantee by such Person of any obligations or indebtedness of others of the
type referred to in the subclauses (A) through (E) of the foregoing clause (i),
whether or not such guarantee is contingent, and whether or not such guarantee
appears on the balance sheet of such Person and (iv) with respect to any
Production Payment, any warranties or guarantees of production or payment by
such Person with respect to such Production Payment, but excluding other
contractual obligations of such Person with respect to any Production Payment.
The amount of any Indebtedness outstanding as of any date shall be (a) the
accreted value thereof, in the case of any Indebtedness that does not require
current payments of interest, and (b) the principal amount thereof in the case
of any other Indebtedness.
"Independent Financial Advisor" means a nationally recognized accounting,
appraisal or investment banking firm that is, in the reasonable judgment of the
Board of Directors, qualified to perform the task for which such firm has been
engaged hereunder and disinterested and independent with respect to the Company
and its Affiliates; provided, that providing accounting, appraisal or investment
banking services to the Company or any of its Affiliates or having an employee,
officer or other representative serving as a member of the Board of Directors of
the Company or any of its Affiliates will not disqualify any firm from being an
Independent Financial Advisor.
"Investments" means, with respect to any Person, all investments by such
Person in other Persons (including Affiliates) in the forms of direct or
indirect loans (including guarantees of Indebtedness or other Obligations),
advances or capital contributions (excluding commission, travel and
entertainment, moving, and similar advances to officers and employees made in
the ordinary course of business), purchases or other acquisitions for
consideration of Indebtedness, Equity Interests or other securities, together
with all items that are or would be classified as investments on a balance sheet
prepared in accordance with GAAP. If the Company or any of its Restricted
Subsidiaries sells or otherwise disposes of any Equity Interests of any direct
or indirect Restricted Subsidiary of the Company such that, after giving effect
to any such sale or disposition, such Person is no longer a direct or indirect
Restricted Subsidiary of the Company, the Company, or such Restricted
Subsidiary, as the case may be, shall be deemed to have made an Investment on
the date of any such sale or disposition equal to the Fair Market Value of the
Equity Interests of such Restricted Subsidiary not sold or disposed of in an
amount determined as provided in the fourth paragraph of the covenant described
above under the caption "-- Certain Covenants -- Restricted Payments."
"Issue Date" means the first date on which the Notes are issued,
authenticated and delivered under the Indenture.
"Lien" means, with respect to any asset, any mortgage, lien, pledge,
charge, security interest or encumbrance of any kind in respect of such asset,
whether or not filed, recorded or otherwise perfected under applicable law
(including any conditional sale or other title retention agreement, any lease in
the nature thereof, any option or other agreement to sell or give a security
interest in any asset and any filing of or agreement to give any financing
statement under the Uniform Commercial Code (or equivalent statutes) of any
jurisdiction).
"Net Income" means, with respect to any Person, the net income (loss) of
such Person, determined in accordance with GAAP and before any reduction in
respect of preferred stock dividends, excluding, however, (i) any gain (but not
loss), together with any related provision for taxes on such gain (but not
loss), realized in connection with (a) any Asset Sale (including, without
limitation, dispositions pursuant to sale and leaseback transactions), or (b)
the disposition of any securities by such Person or any of its Restricted
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Subsidiaries or the extinguishment of any Indebtedness of such Person or any of
its Restricted Subsidiaries and (ii) any extraordinary or nonrecurring gain (but
not loss), together with any related provision for taxes on such extraordinary
or nonrecurring gain (but not loss).
"Net Proceeds" means the aggregate cash proceeds or Cash Equivalents
received by the Company or any of its Restricted Subsidiaries in respect of any
Asset Sale (including, without limitation, any cash received upon the sale or
other disposition of any non-cash consideration received in any Asset Sale), net
of the direct costs relating to such Asset Sale (including, without limitation,
legal, accounting, investment banking and brokers fees, sales and underwriting
commissions and other reasonable costs incurred in preparing such asset for
sale) and any relocation expenses incurred as a result thereof, taxes paid or
reserved as payable as a result thereof (after taking into account any available
tax credits or deductions and any tax sharing arrangements), amounts required to
be applied to the repayment of Indebtedness (other than Indebtedness under any
Credit Facility) secured by a Lien on the asset or assets that were the subject
of such Asset Sale and any reserve for adjustment (whether or not placed in
escrow) in respect of the sale price of such asset or assets established in
accordance with GAAP.
"Non-Recourse Indebtedness" means Indebtedness (i) as to which neither the
Company nor any of its Restricted Subsidiaries, (a) provides any guarantee or
credit support of any kind (including any undertaking, guarantee, indemnity,
agreement or instrument that would constitute Indebtedness) or (b) is directly
or indirectly liable (as a guarantor or otherwise), (ii) the incurrence of which
will not result in any recourse against any of the assets of the Company or its
Restricted Subsidiaries, and (iii) no default with respect to which would permit
(upon notice, lapse of time or both) any holder of any other Indebtedness of the
Company or any of its Restricted Subsidiaries to declare pursuant to the express
terms governing such Indebtedness a default on such other Indebtedness or cause
the payment thereof to be accelerated or payable prior to its Stated Maturity.
"Obligations" means any principal, premium (if any), interest (including
interest accruing on or after the filing of any petition in bankruptcy or for
reorganization relating to the Company or its Restricted Subsidiaries whether or
not a claim for post-filing interest is allowed in such proceeding), penalties,
fees, charges, expenses, indemnifications, reimbursement obligations, damages
(including Liquidated Damages), guarantees (including the Subsidiary Guarantees)
and other liabilities or amounts payable under the documentation governing any
Indebtedness or in respect thereof.
"Permitted Business" means, with respect to the Company and its Restricted
Subsidiaries, the businesses of (i) the acquisition, exploration, development,
operation and disposition of interests in oil, gas and other hydrocarbon
properties, (ii) the acquisition, gathering, treating, processing, storage,
transportation of production from such interests or properties, (iii) the
acquisition, processing, marketing, refining, distilling, storage and/or
transportation of hydrocarbons and/or royalty or other interests in crude oil or
refined or associated products related thereto, (iv) the acquisition, operation,
improvement, leasing and other use of convenience stores, retail service
stations, truck stops and other public accommodations in connection therewith,
(v) the marketing and distribution of petroleum and marine products and the
provision of logistical services to marine and offshore exploration and
production industries, (vi) any business currently engaged in by the Company or
its Restricted Subsidiaries and (vii) any activity or business that is a
reasonable extension, development or expansion of, or reasonably related to, any
of the foregoing.
"Permitted Investments" means (a) any Investment in the Company or in a
Restricted Subsidiary of the Company; (b) any Investment in Cash Equivalents or
deposit accounts maintained in the ordinary course of business consistent with
past practices; (c) any Investment by the Company or any Restricted Subsidiary
of the Company in a Person, if as a result of such Investment (i) such Person
becomes a Restricted Subsidiary of the Company or (ii) such Person is merged,
consolidated or amalgamated with or into, or transfers or conveys all or
substantially all of its assets to, or is liquidated into, the Company or a
Restricted Subsidiary of the Company; (d) any security or other Investment
received or Investment made as a result of the receipt of non-cash consideration
from (i) an Asset Sale that was made pursuant to and in compliance with the
covenant described above under the caption "-- Repurchase at the Option of
Holders -- Asset Sales" or (ii) a disposition of assets that do not constitute
an Asset Sale; (e) any acquisition of assets solely in exchange for
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the issuance of Equity Interests (other than Disqualified Stock) of the Company;
(f) any Investment received in settlement of debts, claims or disputes owed to
the Company or any Restricted Subsidiary of the Company that arose out of
transactions in the ordinary course of business; (g) any Investment received in
connection with or as a result of a bankruptcy, workout or reorganization of any
Person; (h) advances and extensions of credit in the nature of accounts
receivable arising from the sale or lease of goods or services or the licensing
of property in the ordinary course of business; (i) relocation allowances for,
and advances and loans to, employees, officers and directors, approved by the
Board of Directors (or authorized officer) (including, without limitation, loans
and advances the net cash proceeds of which are used solely to purchase Equity
Interests of the Company in connection with restricted stock or employee stock
purchase plans, or to exercise stock received pursuant thereto or other
incentive plans in a principal amount not to exceed the aggregate exercise or
purchase price), or loans to refinance principal and accrued interest on any
such loans, provided that the aggregate principal amount of such loans, advances
and allowances shall not exceed at any time $10 million; (j) other Investments
by the Company or any Restricted Subsidiary of the Company in any Person having
an aggregate Fair Market Value (measured as of the date each such Investment is
made and without giving effect to subsequent changes in value), when taken
together with all other Investments made pursuant to this clause (j) (net of
returns of capital, dividends and interest paid on Investments and sales,
liquidations and redemptions of Investments), not in excess of the greater of
$50 million and 15% of the Consolidated Net Worth of the Company; (k)
Investments in the form of intercompany Indebtedness or Guarantees of
Indebtedness of a Restricted Subsidiary of the Company permitted under clauses
(v) and (xii) of the covenant described under the caption "-- Certain
Covenants -- Incurrence of Indebtedness and Issuance of Preferred Stock;" (l)
Investments arising in connection with Hedging Obligations that are incurred in
the ordinary course of business for the purpose of fixing or hedging currency,
commodity or interest rate risk in connection with the conduct of the business
of the Company and its Subsidiaries and not for speculative purposes; (m)
Investments in the form of, or pursuant to, operating agreements, joint
ventures, partnership agreements, working interests, royalty interests, mineral
leases, processing agreements, farm-out agreements, contracts for the sale,
transportation or exchange of oil and natural gas, unitization agreements,
pooling agreements, area of mutual interests agreements, production sharing
agreements or other similar or customary agreements, transactions, properties,
interests or arrangements, and Investments and expenditures in connection
therewith or pursuant thereto, in each case made or entered into the ordinary
course of the business described in clauses (i) and (ii) of the definition of
"Permitted Business" excluding, however, investments in corporations; and (n)
Investments pursuant to agreements and obligations of the Company and any
Restricted Subsidiary in effect on the Issue Date.
"Permitted Junior Securities" means (i) Equity Interests in the Company or
any Guarantor which, to the extent received by any Holder in connection with any
bankruptcy, reorganization, insolvency or similar proceeding in which any Equity
Interests are also exchanged for or distributed in respect of Senior Debt, are
either common equity securities or are subordinated to all such Equity Interests
so exchanged or distributed to substantially the same extent as, or to a greater
extent than, the Notes are subordinated to Senior Debt pursuant to the
Indenture, and (ii) debt securities that are subordinated to all Senior Debt
(and any debt securities issued in exchange for Senior Debt) to substantially
the same extent as, or to a greater extent than, the Notes are subordinated to
Senior Debt pursuant to the Indenture.
"Permitted Refinancing Indebtedness" means any Indebtedness of the Company
or any of its Restricted Subsidiaries issued in exchange for, or the net
proceeds of which are used to extend, refinance, renew, replace, defease or
refund other Indebtedness of the Company or any of its Restricted Subsidiaries
(other than intercompany Indebtedness), including Indebtedness that extends,
refinances, renews, replaces, defeases or refunds Permitted Refinancing
Indebtedness, provided that: (i) the principal amount (or accreted value, if
applicable) of such Permitted Refinancing Indebtedness does not exceed the
principal amount of (or accreted value, if applicable), plus accrued and unpaid
interest on, the Indebtedness so extended, refinanced, renewed, replaced,
defeased or refunded (plus fees and expenses incurred in connection therewith,
including any premium or defeasance cost); (ii) such Permitted Refinancing
Indebtedness has a final maturity date later than the final maturity date of,
and has a Weighted Average Life to Maturity equal to or greater than the
Weighted Average Life to Maturity of, the Indebtedness being extended,
refinanced, renewed, replaced, defeased or refunded; (iii) if the Indebtedness
being extended, refinanced, renewed, replaced, defeased or
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refunded is subordinated in right of payment to the Notes, such Permitted
Refinancing Indebtedness has a final maturity date later than the final maturity
date of, and is subordinated in right of payment to, the Notes on terms at least
as favorable to the Holders of Notes as those contained in the documentation
governing the Indebtedness being extended, refinanced, renewed, replaced,
defeased or refunded; and (iv) such Indebtedness is incurred either by the
Company or a Restricted Subsidiary who is the obligor on the Indebtedness being
extended, refinanced, renewed, replaced, defeased or refunded.
"Person" means any individual, corporation, partnership, joint venture,
association, joint stock company, trust, limited liability company,
unincorporated organization, government or any agency or political subdivision
thereof or any other entity.
"Production Payment" means, collectively, Dollar-Denominated Production
Payments and Volumetric Production Payments.
"Public Equity Offering" means any public underwritten offering of the
Voting Stock (other than Disqualified Stock) of the Company pursuant to
registration under the Securities Act of 1933, as amended, made pursuant to an
underwriting or similar agreement executed and delivered after the Issue Date.
"Regulation S" means Regulation S promulgated under the Securities Act.
"Representative" means the administrative agent under the Senior Credit
Facility or its successor thereunder or any other agent or representative on
behalf of the holders of Designated Senior Debt.
"Restricted Investment" means an Investment other than a Permitted
Investment.
"Restricted Subsidiary" of a Person means any Subsidiary of the referenced
Person that is not an Unrestricted Subsidiary or a direct or indirect Subsidiary
of an Unrestricted Subsidiary; provided that, on the Issue Date, all
Subsidiaries of the Company shall be Restricted Subsidiaries of the Company.
"Senior Credit Facility" means that certain Third Amended and Restated
Credit Agreement, dated as of the Issue Date, by and among the Company, Lehman
Brothers Inc., as Arranger, Lehman Commercial Paper Inc., as Syndication Agent,
and certain other lenders and agents, providing for up to $200 million of term
loan borrowings and $300 million of revolving credit borrowings and letters of
credit in each case, including any related notes, guarantees, collateral
documents, instruments and agreements executed in connection therewith and in
each case as amended, modified, renewed, restated, refunded, replaced or
refinanced (in each case, without limitation as to amount), in whole or in part,
from time to time and any agreements (and related documents) governing
Indebtedness incurred to refund or refinance credit extensions and commitments
then outstanding or permitted to be outstanding under such Senior Credit
Facility, whether by the same or any other lender or group of lenders. The
Company shall promptly notify the Trustee of any other lender or group of
lenders. The Company shall promptly notify the Trustee of any such refunding or
refinancing of the existing Senior Credit Facility.
"Senior Debt" means (i) Indebtedness of the Company or any Guarantor for
money borrowed and all obligations of such Person under, or with respect to, the
Senior Credit Facility or any other Credit Facility, whether direct or indirect,
under guarantees, letters of credit, foreign currency or interest rate swaps,
foreign exchange contracts, caps, collars, options, hedges or other agreements
or arrangements designed to protect against fluctuations in currency values or
interest rates, other extensions of credit, expenses, fees, reimbursements,
indemnities and all other amounts (including interest at the contract rate
accruing on or after the filing of any petition in bankruptcy or reorganization
relating to the Company or any Guarantor whether or not a claim for post-filing
interest is allowed in such proceeding), (ii) the principal of and premium, if
any, and accrued and unpaid interest, whether existing on the date hereof or
hereafter incurred, in respect of (A) indebtedness of the Company or any
Guarantor for money borrowed, (B) guarantees by the Company or any Guarantor of
indebtedness for money borrowed by any other Person, (C) indebtedness evidenced
by notes, debentures, bonds, or other instruments for the payment of which the
Company or any Guarantor is responsible or liable, by guarantees or otherwise,
(D) obligations of the Company or any Guarantor for the reimbursement of any
obligor on any letter of credit, banker's acceptance or similar credit
transaction, (E) obligations of the Company or any Guarantor under any agreement
to lease, or any lease of, any real or
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personal property which, in accordance with GAAP, is classified on the Company's
or any Guarantor's consolidated balance sheet as a liability, and (F)
obligations of the Company or any Guarantor under interest rate swaps, caps,
collars, options and similar arrangements and commodity or foreign currency
hedges and (iii) modifications, renewals, extensions, replacements, refinancings
and refundings of any such indebtedness, obligations or guarantees, unless, in
the instrument creating or evidencing the same or pursuant to which the same is
outstanding, it is expressly provided that such indebtedness, obligations or
guarantees, or such modifications, renewals, extensions, replacements,
refinancings or refundings thereof, are not superior in right of payment to the
Notes; provided that Senior Debt will not be deemed to include (a) Indebtedness
represented by preferred stock, (b) any obligation of the Company or any
Guarantor to any Subsidiary or other Affiliate, (c) any liability for federal,
state, local or other taxes owed or owing by the Company or any Guarantor, (d)
any accounts payable or other liability to trade creditors, (e) any
Indebtedness, guarantee or obligation of the Company or any Guarantor which is
expressly subordinate or junior by its terms in right of payment to any other
Indebtedness, guarantee or obligation of the Company or any Guarantor, (f) that
portion of any Indebtedness incurred in violation of the covenant described
above under the caption "-- Certain Covenants -- Incurrence of Indebtedness and
Issuance of Preferred Stock" (other than Indebtedness incurred under a Credit
Facility if prior to the incurrence thereof or, in the case of contingent
obligations such as letters of credit pursuant to which such Indebtedness is
incurred, prior to the issuance thereof or agreement to extend credit in respect
thereof, the Company has certified to the lenders under such Credit Facility
that the such incurrence or extension of credit does not violate such covenant)
or (g) Indebtedness of the Company or any Guarantor which is classified as
non-recourse in accordance with GAAP or any unsecured claim arising in respect
thereof by reason of the application of section 1111(b)(1) of the Bankruptcy
Code.
"Significant Subsidiary" means any Subsidiary that would be a "significant
subsidiary" as defined in Article 1, Rule 1-02 of Regulation S-X, promulgated
pursuant to the Securities Act, as such Regulation is in effect on the Issue
Date.
"Stated Maturity" means, with respect to any installment of interest or
principal, or sinking fund or mandatory redemption of principal, on any series
of Indebtedness, the date on which such payment of interest or principal was
scheduled to be paid or made, as applicable, in the original documentation
governing such Indebtedness, and shall not include any contingent obligations to
repay, redeem or repurchase any such interest or principal prior to the date
originally scheduled for the payment thereof.
"Subsidiary" means, with respect to any Person, (i) any corporation,
association or other business entity of which more than 50% of the total voting
power of shares of Capital Stock entitled (without regard to the occurrence of
any contingency) to vote in the election of directors, managers or trustees
thereof is at the time owned or controlled, directly or indirectly, by such
Person and (ii) any partnership (a) the sole general partner or the managing
general partner of which is such Person or an entity described in clause (i) and
related to such Person or (b) the only general partners of which are such Person
or of one or more entities described in clause (i) and related to such Person
(or any combination thereof).
"Subsidiary Guarantee" means the guarantee of the Notes and the Exchange
Notes by each of the Guarantors pursuant to the Indenture and in the form of
guarantee endorsed on the form of Note attached as Exhibit A-1 or A-2 to the
Indenture and any additional guarantee of the Notes and the Exchange Notes to be
executed by any Subsidiary of the Company pursuant to the covenant described
above under the caption "-- Certain Covenants -- Additional Subsidiary
Guarantees."
"Unrestricted Subsidiary" means (i) any Subsidiary of the Company
(including any newly acquired or newly formed Subsidiary of the Company) that is
designated by the Board of Directors as an Unrestricted Subsidiary pursuant to a
resolution of the Board of Directors as certified in an Officers' Certificate
delivered to the Trustee and (ii) each Subsidiary of an Unrestricted Subsidiary,
whenever it shall become such a Subsidiary. The Board of Directors may designate
any Subsidiary of the Company to become an Unrestricted Subsidiary if it (a) has
no Indebtedness other than Non-Recourse Indebtedness; (b) is not party to any
agreement, contract, arrangement or understanding with the Company or any
Restricted Subsidiary of the Company unless the terms of any such agreement,
contract, arrangement or understanding are no less
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favorable to the Company or such Restricted Subsidiary than those that might be
obtained, in light of all the circumstances, at the time from Persons who are
not Affiliates of the Company; (c) is a Person with respect to which neither the
Company nor any of its Restricted Subsidiaries has any direct or indirect
obligation (x) to subscribe for additional Equity Interests or (y) to maintain
or preserve such Persons' financial condition or to cause such Persons to
achieve any specified levels of operating results; (d) has not guaranteed or
otherwise directly or indirectly provided credit support for any Indebtedness of
the Company or any of its Restricted Subsidiaries; (e) does not own any Capital
Stock of or own or hold any Lien on any property of, the Company or any
Restricted Subsidiary of the Company; and (f) would constitute an Investment
which the Company could make in compliance with the covenant under the caption
"-- Certain Covenants -- Restricted Payments." Notwithstanding the foregoing,
if, at any time, any Unrestricted Subsidiary would fail to meet the foregoing
requirements as an Unrestricted Subsidiary, it shall thereafter cease to be an
Unrestricted Subsidiary for purposes of the Indenture and any Indebtedness of
such Subsidiary shall be deemed to be incurred as of such date.
"Volumetric Production Payments" means production payment obligations
recorded as deferred revenue in accordance with GAAP, together with all
undertakings and obligations in connection therewith.
"Voting Stock" of any Person as of any date means the Capital Stock of such
Person that is at the time entitled to vote in the election of the Board of
Directors of such Person.
"Weighted Average Life to Maturity" means, when applied to any Indebtedness
at any date, the number of years obtained by dividing (i) the sum of the
products obtained by multiplying (a) the amount of each then remaining
installment, sinking fund, serial maturity or other required payments of
principal, including payment at final maturity, in respect thereof, by (b) the
number of years (calculated to the nearest one-twelfth) that will elapse between
such date and the making of such payment, by (ii) the then outstanding principal
amount of such Indebtedness.
"Wholly Owned Restricted Subsidiary" of a Person means a Restricted
Subsidiary of such Person to the extent (i) all of the outstanding Capital Stock
and other Equity Interests of which (other than director's qualifying shares)
shall be directly or indirectly owned by such Person or (ii) such Restricted
Subsidiary is organized in a foreign jurisdiction and is required by the
applicable laws and regulations of such jurisdiction to be partially owned by
the government of such foreign jurisdiction or individual or corporate citizens
of such foreign jurisdiction or another foreign jurisdiction in order for such
Restricted Subsidiary to transact business in such foreign jurisdiction,
provided that such Person, directly or indirectly, owns the remaining Capital
Stock or ownership interests in such Restricted Subsidiary and, by contract or
otherwise, derives the economic benefits of ownership of such Restricted
Subsidiary to substantially the same extent as if such Restricted Subsidiary
were a wholly owned Restricted Subsidiary.
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DESCRIPTION OF CAPITAL STOCK
COMMON STOCK
The Company's Restated Certificate of Incorporation, as amended, currently
authorizes the Company to issue up to 100,000,000 shares of Common Stock. The
holders of Common Stock are entitled to one vote for each share held of record
on all matters submitted to a vote of stockholders. Subject to preferences that
may be applicable to any outstanding Preferred Stock (as defined herein),
holders of Common Stock are entitled to receive ratably such dividends as may be
declared by the Board of Directors of the Company out of funds legally available
therefor. In the event of a liquidation, dissolution, or winding up of the
Company, holders of Common Stock are entitled to share ratably in all assets
remaining after payment of liabilities and liquidation preference of any
outstanding Preferred Stock. Holders of Common Stock have no preemptive rights
and have no rights to convert their Common Stock into any other securities.
There are no redemption provisions with respect to any shares of Common Stock.
All of the outstanding shares of Common Stock are, and the Common Stock offered
hereby will be, upon issuance against full payment of the purchase price
therefor, fully paid and nonassessable. As of July 8, 1998 there were issued and
outstanding 32,311,918 shares of Common Stock.
The transfer agent and registrar for the Common Stock is ChaseMellon
Shareholder Services L.L.C.
PREFERRED STOCK
The Company's authorized capital stock includes 5,000,000 shares of
preferred stock, no par value per share (the "Preferred Stock"). The Preferred
Stock may be issued in series, and shares of each series will have such rights
and preferences as are fixed by the Board of Directors in resolutions
authorizing the issuance of that particular series. In designating any series of
Preferred Stock, the Board of Directors may, without further action by the
holders of the Common Stock, fix the number of shares constituting that series
and fix the dividend rights, dividend rate, conversion rights, voting rights
(which may be greater or lesser than the voting rights of the Common Stock),
rights and terms of redemption (including any sinking fund provisions), and the
liquidation preferences of such series of Preferred Stock. Holders of any series
of Preferred Stock, when and if issued, may have priority claims to dividends
and to any distributions upon liquidation of the Company, and other preferences
over the holders of the Common Stock. As of July 8, 1998, there were issued and
outstanding 103,500 shares of Preferred Stock.
MANDATORILY CONVERTIBLE PREFERRED STOCK
Pursuant to the PIES Offering, the Company issued PIES, each representing
one one-hundredth of a share of Mandatorily Convertible Preferred Stock
deposited under a Deposit Agreement (the "Deposit Agreement"), among the
Company, The Bank of New York as depositary (the "Depositary"), and the holders
from time to time of depositary receipts executed and delivered thereunder (the
"Depositary Receipts").
Dividends. Holders of the PIES are entitled to receive, through the
Depositary, when, as and if declared on the Mandatorily Convertible Preferred
Stock represented thereby by the Board of Directors, cash dividends out of funds
legally available therefor from the date of initial issuance of the PIES (which
issuance will be evidenced by the initial issuance of the Depositary Receipts)
at the rate of 7 1/4% per annum or 1.8125% per quarter. Dividends will cease to
become payable by the Company to the Depositary for distribution to the holders
of the PIES when dividends cease to accrue on the Mandatorily Convertible
Preferred Stock represented thereby on the Mandatory Conversion Date or on the
date of the earlier conversion of the PIES at the option of the holder.
Dividends will be paid out of funds legally available therefor.
Mandatory Conversion of PIES. Unless voluntarily converted into Common
Stock prior thereto, on July 1, 2001 (the "Mandatory Conversion Date"), each
PIES will automatically convert into a number of shares of Common Stock at the
Conversion Rate (as defined below) and the holder thereof will have the right to
receive cash in an amount equal to the accrued and unpaid dividends on the
Mandatorily Convertible Preferred Stock represented by such PIES to the
Mandatory Conversion Date (other than previously declared dividends deliverable
to a holder of record of the Depositary Receipt evidencing such PIES as of a
prior date), whether or not declared, out of funds legally available for the
payment of dividends, subject to any applicable requirements of other Preferred
Stock. The "Conversion Rate" is equal to (a) if the Conversion Price (as
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defined below) is greater than or equal to $18.85 (the "Threshold Appreciation
Price"), 0.8455 shares of Common Stock per PIES, (b) if the Conversion Price is
less than the Threshold Appreciation Price but is greater than $15.9375 (the
"Initial Price"), a fraction, equal to the Initial Price divided by the
Conversion Price, of one share of Common Stock per PIES and (c) if the
Conversion Price is less than or equal to the Initial Price, one share of Common
Stock per PIES. The Conversion Rate, the Threshold Appreciation Price and the
Initial Price are each subject to adjustment in certain circumstances, including
if the Company shall (a) pay a stock dividend or make a distribution with
respect to its Common Stock in shares of Common Stock, (b) subdivide or split
its outstanding Common Stock, (c) combine its outstanding Common Stock into a
smaller number of shares, (d) issue by reclassification of its shares of Common
Stock any shares of Common Stock, (e) issue rights or warrants to all holders of
its Common Stock entitling them to subscribe for or purchase shares of Common
Stock at a price per share less than the Current Market Price (as defined in the
Certificate of Designation) of the Common Stock on the record date for the
determination of stockholders entitled to receive such rights or warrants, or
(f) pay certain dividends or distribute to all holders of its Common Stock
evidences of its indebtedness, cash or other assets or issue rights or warrants
(other than those referred to in clause (e) above) to all holders of its Common
Stock entitling them to subscribe for or purchase any of its securities.
The "Conversion Price" is the average Closing Price per share of Common
Stock for the 20 trading days immediately prior to (but not including) the
Mandatory Conversion Date; provided, however, that, if there are not 20 trading
days for the Common Stock occurring later than the 60th calendar day immediately
prior to, but not including, the Mandatory Conversion Date, the "Conversion
Price" will be the market value per share of Common Stock as of the Mandatory
Conversion Date as determined by a nationally recognized investment banking firm
retained for such purpose by the Company. The Conversion Price is subject to
adjustment in certain circumstances.
Conversion at the Option of the Holder. The PIES are convertible, in whole
but not in part, at the option of the holders thereof, at any time after July
26, 1998 and prior to the Mandatory Conversion Date, into shares of Common Stock
at a rate of 0.8455 shares of Common Stock for each PIES (the "Optional
Conversion Rate"), equivalent, for each PIES, to a conversion price of $18.85
per share of Common Stock (the "Optional Conversion Price"), subject to
adjustment in the circumstances described above with respect to the Conversion
Rate.
Liquidation Rights. In the event of any voluntary or involuntary
liquidation, dissolution or winding up of the Company, and subject to the rights
of holders of any other series of Preferred Stock, the holders of PIES will be
entitled to receive an amount equal to the per share price to the public of the
PIES plus accrued and unpaid dividends on the Mandatorily Convertible Preferred
Stock represented thereby, out of the assets of the Company available for
distribution to stockholders, before any distribution of assets is made to
holders of junior ranking stock upon liquidation, dissolution or winding up.
Voting Rights. The holders of shares of Mandatorily Convertible Preferred
Stock (including shares of Mandatorily Convertible Preferred Stock represented
by PIES) are not entitled to any voting rights, except as required by applicable
state law and as described below.
In the event that dividends on the Mandatorily Convertible Preferred Stock
(including shares of Mandatorily Convertible Preferred Stock represented by
PIES) or any other series of Preferred Stock are in arrears and unpaid for six
quarterly dividend periods, or if any other series of Preferred Stock shall be
entitled for any other reason to exercise voting rights, separate from the
Common Stock to elect any Directors of the Company ("Preferred Stock
Directors"), the holders of the shares of Mandatorily Convertible Preferred
Stock (voting separately as a class with holders of all other series of
Preferred Stock which do not have a separate class vote and upon which like
voting rights have been conferred and are exercisable), will be entitled to vote
for the election of two Preferred Stock Directors, such Directors to be in
addition to the number of Directors constituting the Board of Directors
immediately prior to the accrual of such right.
The Company will not, without the approval of the holders of at least
66 2/3% of all the shares of Mandatorily Convertible Preferred Stock then
outstanding: (i) amend, alter or repeal any of the provisions of the Restated
Certificate of Incorporation or the Bylaws of the Company so as to affect
adversely the powers, preferences or rights of the holders of the shares of
Mandatorily Convertible Preferred Stock then outstanding
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or reduce the minimum time required for any notice to which only the holders of
the shares of Mandatorily Convertible Preferred Stock then outstanding may be
entitled; (ii) create any series of Preferred Stock ranking prior to the shares
of Mandatorily Convertible Preferred Stock as to payment of dividends or the
distribution of assets upon liquidation; or (iii) authorize or create, or
increase the authorized amount of, any capital stock, or any security
convertible into capital stock, of any class ranking prior to the shares of
Mandatorily Convertible Preferred Stock as to payment of dividends or the
distribution of assets upon liquidation.
Holders of PIES and Mandatorily Convertible Preferred Stock have no
preemptive rights.
CERTAIN FEDERAL INCOME TAX CONSIDERATIONS
The following is a summary of the material United States federal income tax
consequences of the Exchange Offer and the purchase, ownership and disposition
of Exchange Notes relevant to initial purchasers of the Old Notes. This summary
is based on currently existing provisions of the Code, existing and temporary
Treasury regulations promulgated thereunder, and administrative and judicial
interpretations thereof, all as in effect on the date hereof and all of which
are subject to change, possibly with retroactive effect, or different
interpretations. This discussion does not address the tax consequences to
subsequent purchasers of Exchange Notes and is limited to initial purchasers of
Old Notes who hold the Old Notes and Exchange Notes as capital assets, within
the meaning of section 1221 of the Code. Moreover, this discussion is for
general information only and does not address all of the tax consequences that
may be relevant to particular initial purchasers of Old Notes in light of their
personal circumstances or to certain types of initial purchasers of Old Notes
(such as certain financial institutions, insurance companies, tax-exempt
entities, dealers in securities, or persons who have hedged the risk of owning
an Old Note or Exchange Note) or the effect of any applicable state, local or
foreign tax law.
PROSPECTIVE PURCHASERS ARE URGED TO CONSULT THEIR OWN TAX ADVISORS AS TO
THE PARTICULAR TAX CONSEQUENCES TO THEM OF THE EXCHANGE OFFER AND OF THE
PURCHASE, OWNERSHIP AND DISPOSITION OF THE EXCHANGE NOTES, INCLUDING THE
APPLICABILITY OF ANY FEDERAL TAX LAWS OR ANY STATE, LOCAL OR FOREIGN TAX LAWS,
AND ANY CHANGES (OR PROPOSED CHANGES) IN APPLICABLE TAX LAWS OR INTERPRETATIONS
THEREOF.
As used herein, the term "U.S. Holder" means an individual who is a citizen
or resident of the United States (including certain former citizens and former
long-term residents), a corporation, partnership or other entity created or
organized in or under the laws of the United States or any political subdivision
thereof, an estate, the income of which is subject to United States federal
income taxation regardless of its source, or a trust if (i) a U.S. court is able
to exercise primary supervision over the administration of the trust and (ii)
one or more U.S. persons have authority to control all substantial decisions of
the trust. A "Non-U.S. Holder" is a holder who is not a U.S. Holder.
Exchange of Notes
The exchange of an Old Note by a U.S. Holder for an Exchange Note pursuant
to the Exchange Offer should not constitute a taxable exchange for United States
federal income tax purposes. Accordingly, there should be no United States
federal income tax consequences to holders who exchange Old Notes for Exchange
Notes pursuant to the Exchange Offer, and any such holder should have the same
adjusted tax basis and holding period in the Exchange Notes as it had in the Old
Notes immediately before the exchange.
Payment of Interest on Exchange Notes
Interest paid or payable on an Exchange Note will be taxable to a U.S.
Holder as ordinary interest income, generally at the time it is received or
accrued, in accordance with such U.S. Holder's regular method of accounting for
United States federal income tax purposes.
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Sale, Exchange or Retirement of the Exchange Notes
Upon the sale, exchange, redemption, retirement at maturity or other
disposition of an Exchange Note, the U.S. Holder generally will recognize
taxable gain or loss equal to the difference between the sum of cash plus the
fair market value of all other property received on such disposition (except to
the extent such cash or property is attributable to accrued but unpaid interest,
which will be taxable as ordinary income) and such U.S. Holder's adjusted tax
basis in the Exchange Note. A U.S. Holder's adjusted tax basis in an Exchange
Note generally will equal the U.S. Holder's adjusted basis for the Old Note
exchanged therefor, less any principal payments received by such U.S. Holder.
Gain or loss recognized by a U.S. Holder on the disposition of an Exchange
Note generally will be capital gain or loss and will be long-term capital gain
or loss if, at the time of such disposition, the U.S. Holder's holding period
for the Exchange Note is more than one year. The deduction of capital losses is
subject to certain limitations. U.S. Holders of Exchange Notes should consult
tax advisors regarding the treatment of capital gains and losses.
Backup Withholding and Information Reporting
Backup withholding and information reporting requirements may apply to
certain payments ("reportable payments') of principal, premium, if any, and
interest on an Exchange Note to a U.S. Holder, and to proceeds paid to a U.S.
Holder from the sale or redemption of an Exchange Note before maturity. The
Company, its agent, a broker, the Trustee or any paying agent, as the case may
be, will be required to withhold from any reportable payment that is subject to
backup withholding a tax equal to 31% of such payment if a U.S. Holder fails to
furnish his taxpayer identification number (social security or employer
identification number), certify that such number is correct, certify that such
holder is not subject to backup withholding or otherwise comply with the
applicable requirements of the backup withholding rules. Certain holders,
including all corporations, are not subject to backup withholding and reporting
requirements. Any amounts withheld under the backup withholding rules from a
reportable payment to a U.S. Holder will be allowed as a credit against such
U.S. Holder's United States federal income tax and may entitle the U.S. Holder
to a refund, provided that the required information is furnished to the Internal
Revenue Service.
The amount of any reportable payments, including interest, made to the
record U.S. Holders of Exchange Notes (other than to holders which are exempt
recipients) and the amount of tax withheld, if any, with respect to such
payments will be reported to such U.S. Holders and to the IRS for each calendar
year.
NON-U.S. HOLDERS
The following discussion is a summary of certain United States federal
income tax and estate tax consequences to a Non-U.S. Holder that holds an
Exchange Note. No United States federal withholding tax will be imposed with
respect to the payment by the Company or its paying agent of principal, premium,
if any, or interest on an Exchange Note owned by a Non-U.S. Holder (the
"Portfolio Interest Exception"), provided that (i) the Non-U.S. Holder does not
actually or constructively own 10% or more of the total combined voting power of
all classes of stock of the Company entitled to vote and is not a controlled
foreign corporation with respect to the United States that is related to the
Company actually or constructively through stock ownership and (ii) the Company,
its paying agent or the person who would otherwise be required to withhold tax
receives either (A) a statement, which may be provided on a Form W-8 or
substitute form (an "Owner's Statement") signed under penalties of perjury by
the beneficial owner of the Exchange Note in which the owner certifies that the
owner is not a United States person, or, in the case of an individual, that he
is neither a citizen nor a resident of the United States, and which provides the
owner's name and address, or (B) a statement signed under penalties of perjury
by the Financial Institution holding the Exchange Note on behalf of the
beneficial owner, together with a copy of the Owner's Statement. As used herein,
the term "Financial Institution" means a securities clearing organization, bank
or other financial institution that holds customers' securities in the ordinary
course of its trade or business that holds an Exchange Note on behalf of the
owner of the Exchange Note. A Non-U.S. Holder who does not qualify for the
Portfolio Interest Exception, would, under current law, generally be subject to
U.S. federal withholding tax at a flat rate of 30% (or lower
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applicable treaty rate) on interest payments. However, a Non-U.S. Holder will
not be subject to the 30% withholding tax if such Non-U.S. Holder provides the
Company with an IRS Form 4224 (or substitute form) stating that the interest
paid on the Exchange Notes is not subject to withholding tax because it is
effectively connected with the beneficial owner's conduct of a trade or business
in the United States.
In general, gain recognized by a Non-U.S. Holder upon the redemption,
retirement, sale, exchange or other disposition of an Exchange Note will not be
subject to United States federal income tax unless such gain or loss is
effectively connected with a trade or business in the United States. However, a
Non-U.S. Holder may be subject to United States federal income tax at a flat
rate of 30% (unless exempt by an applicable treaty) on any such gain if the
Non-U.S. Holder is an individual present in the United States for 183 days or
more during the taxable year of the disposition of the Exchange Note and certain
other requirements are met.
Backup withholding and information reporting requirements do not apply to
payments of interest made by the Company or a paying agent to a Non-U.S. Holder
if the Owner's Statement described above is received, provided that the payor
does not have actual knowledge that the holder is a U.S. Holder. If any payments
of principal and interest are made to the beneficial owner of an Exchange Note
by or through the foreign office of a foreign custodian, foreign nominee or
other foreign agent of such beneficial owner, or if the foreign office of a
foreign "broker" (as defined in applicable Treasury regulations) pays the
proceeds of the sale of an Exchange Note to the seller thereof, backup
withholding and information reporting will not apply. Information reporting
requirements (but not backup withholding) will apply, however, to a payment by a
foreign office of a broker that is (i) a United States person, (ii) a foreign
person that derives 50% or more of its gross income for certain periods from the
conduct of a trade or business in the United States or (iii) a "controlled
foreign corporation" (generally, a foreign corporation controlled by certain
United States shareholders) with respect to the United States unless the broker
has no documentary evidence in its records that the holder is a Non-U.S. Holder
and certain other conditions are met or the holder otherwise establishes an
exemption. Payment by a United States office of a broker is subject to both
backup withholding at a rate of 31% and information reporting unless the holder
certifies under penalties of perjury that it is a Non-U.S. Holder or otherwise
establishes an exemption.
Recently issued Treasury regulations modify certain of the certification
requirements described above. These modifications will become generally
effective for interest payments made beginning January 1, 2000. The Company or
its paying agent may request new withholding exemption forms from holders in
order to qualify for continued exemption from withholding under the Treasury
regulations when they become effective. For example, under recently issued
Treasury regulations, a Non-U.S. Holder will be required to provide a Form W-8
(or substitute form) to the withholding agent on which such holder provides its
name, address and taxpayer identification number and states, under penalty of
perjury, that the interest paid on an Exchange Note and the gain on the sale,
exchange or other disposition of an Exchange Note is not effectively connected
with such holder's United States trade or business in order to obtain an
exemption from withholding tax on payments made beginning January 1, 2000.
If a Non-U.S. Holder is engaged in a trade or business in the United States
and if interest on an Exchange Note is effectively connected with the conduct of
such trade or business, the Non-U.S. Holder, although exempt from United States
federal withholding tax as discussed above, will be subject to United States
federal income tax on such interest and on gain realized on the sale, exchange
or other disposition of an Exchange Note on a net income basis in the same
manner as if the holder were a U.S. Holder. In addition, if such holder is a
foreign corporation, it may be subject to a branch profits tax equal to 30%, or
applicable lower tax treaty rate, of its effectively connected earnings and
profits for the taxable year, subject to adjustments. For this purpose, interest
and gain on an Exchange Note will be included in such foreign corporation's
effectively connected earnings and profits.
Subject to applicable estate tax treaty provisions, Exchange Notes held at
the time of death (or Exchange Notes transferred before death but subject to
certain retained rights or powers) by an individual who at the time of death is
a Non-U.S. Holder will not be included in such Non-U.S. Holder's gross estate
for United States federal estate tax purposes provided that the individual does
not actually or constructively own 10% or more of the total combined voting
power of all classes of stock of the Company entitled to vote or hold the
Exchange Notes in connection with a United States trade or business.
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PLAN OF DISTRIBUTION
Each broker-dealer that receives Exchange Notes for its own account
pursuant to the Exchange Offer must acknowledge that it will deliver a
prospectus in connection with any resale of such Exchange Notes. This
Prospectus, as it may be amended or supplemented from time to time, may be used
by a broker-dealer in connection with resales of Exchange Notes received in
exchange for Old Notes where such Old Notes were acquired as a result of
market-making activities or other trading activities. The Company has agreed
that it will make this Prospectus, as amended or supplemented, available to any
broker-dealer for use in connection with any such resale.
The Company will not receive any proceeds from any sale of Exchange Notes
by broker-dealers. Exchange Notes received by broker-dealers for their own
account pursuant to the Exchange Offer may be sold from time to time in one or
more transactions in the over-the-counter market, in negotiated transactions,
through the writing of options on the Exchange Notes or a combination of such
methods of resale, at market prices prevailing at the time of resale, at prices
related to such prevailing market prices or at negotiated prices. Any such
resale may be made directly to purchasers or to or through brokers or dealers
who may receive compensation in the form of commissions or concessions from any
such broker-dealer or the purchasers of any such Exchange Notes. Any
broker-dealer that resells Exchange Notes that were received by it for its own
account pursuant to the Exchange Offer and any broker or dealer that
participates in a distribution of such Exchange Notes may be deemed to be an
"underwriter" within the meaning of the Securities Act and any profit on any
such resale of Exchange Notes and any commission or concessions received by any
such person may be deemed to be underwriting compensation under the Securities
Act. The Letter of Transmittal states that, by acknowledging that it will
deliver and by delivering a prospectus, a broker-dealer will not be deemed to
admit that it is an "underwriter," within the meaning of the Securities Act.
The Company will promptly send additional copies of this Prospectus and any
amendment or supplement to this Prospectus to any broker-dealer that requests
such documents in the Letter of Transmittal. The Company has agreed to pay all
expenses incident to the Exchange Offer, other than commissions or concessions
of any broker-dealer, and will indemnify the holders of the Notes (including any
broker-dealers) against certain liabilities including liabilities under the
Securities Act.
LEGAL MATTERS
Certain legal matters in connection with the Exchange Notes will be passed
upon for the Company by Fulbright & Jaworski L.L.P., Houston, Texas.
EXPERTS
The Tesoro Consolidated Financial Statements as of December 31, 1997 and
1996 and for each of the three years in the period ended December 31, 1997,
included in this Prospectus, have been audited by Deloitte & Touche LLP,
independent auditors, as stated in their report appearing herein and have been
so included in reliance upon the reports of such firm given upon their authority
as experts in accounting and auditing.
The combined balance sheets of BHP Petroleum Americas Refining Inc. and BHP
Petroleum South Pacific Inc. as of May 31, 1997 and 1996, and the related
combined statements of operations, stockholders' equity and cash flows for each
of the three years in the period ended May 31, 1997 included in this Prospectus,
have been audited by Arthur Andersen LLP, independent public accountants, as
indicated in their report with respect thereto, and are included herein in
reliance upon the authority of said firm as experts in accounting and auditing
in giving said report.
The financial statements of Shell Anacortes Refining Company as of December
31, 1997 and 1996 and for the period from inception (January 4, 1996) through
December 31, 1996 and for the year ended December 31, 1997 included in this
Prospectus have been so included in reliance on the report of
PricewaterhouseCoopers LLP, independent accountants, given on authority of said
firm as experts in auditing and accounting.
133
<PAGE> 137
The information for the year ended December 31, 1997 relating to estimated
proved reserves of oil and gas and the related estimates of future net cash
flows and present values thereof as of December 31, 1995, December 31, 1996 and
December 31, 1997, included in this Prospectus have been prepared by Netherland,
Sewell & Associates, Inc., independent petroleum engineers, and are included
herein upon the authority of such firm as an expert in petroleum engineering.
AVAILABLE INFORMATION
The Company has filed with the SEC a registration statement (the
"Registration Statement") under the Securities Act on Form S-4 with respect to
the Exchange Notes offered hereby. This Prospectus does not contain all of the
information set forth in the Registration Statement and the exhibits thereto,
certain parts of which are omitted in accordance with the rules and regulations
of the SEC. Statements made in this Prospectus as to the contents of any
contract, agreement or other document referred to are not necessarily complete.
With respect to each such contract, agreement or other document filed as an
exhibit to the Registration Statement, reference is made to the exhibit for a
more complete description of the matter involved. The Registration Statement and
any amendments thereto, including exhibits filed or incorporated by reference as
a part thereof, are available for inspection and copying at the SEC's offices as
described below.
The Company is subject to the informational requirements of the Securities
Exchange Act of 1934, as amended (the "Exchange Act"), and, in accordance
therewith, files reports, proxy statements and other information with the
Commission. Such reports, proxy statements and other information may be
inspected and copied at the public reference facilities maintained by the
Commission at 450 Fifth Street, N.W., Washington, D.C. 20549, and at the
following Regional Offices of the Commission: 7 World Trade Center, Suite 1300,
New York, New York 10048; and Northwestern Atrium, 500 West Madison Street,
Suite 1400, Chicago, Illinois 60661-2511. Copies of such material also may be
obtained at prescribed rates from the Public Reference Section of the
Commission, 450 Fifth Street, N.W., Washington, D.C. 20549. Such material also
may be accessed electronically by means of the Commission's home page on the
Internet at http://www.sec.gov. The Common Stock is listed for trading on the
NYSE and the Pacific Stock Exchange (the "PSE") under the trading symbol "TSO,"
and the Premium Income Equity Securities are listed on the NYSE under the
trading symbol "TSOprA." Reports, proxy statements and other information
concerning the Company may be inspected at the offices of the NYSE, 20 Broad
Street, New York, New York 10005, and at the offices of the PSE, 301 Pine
Street, San Francisco, California 94104.
INCORPORATION OF CERTAIN DOCUMENTS BY REFERENCE
The following documents heretofore filed with the Commission by the Company
pursuant to the Exchange Act are incorporated herein by reference:
1. The Company's Annual Report on Form 10-K for the fiscal year ended
December 31, 1997, as amended on Form 10-K/A, filed April 30, 1998.
2. The Company's Report on Form 10-Q for the quarterly period ended
March 31, 1998.
3. The Company's Current Report on Form 8-K, dated as of May 13, 1998.
4. The Company's Current Report on Form 8-K, dated as of June 5, 1998.
5. The Company's Current Report on Form 8-K, dated as of July 1, 1998.
6. The description of the Premium Income Equity Securities included in
the Company's Registration Statement on Form 8-A dated June 25, 1998.
7. The description of the Common Stock included in the Company's
Registration Statement on Form 8-A dated April 21, 1969, as amended by a
Form 8 dated April 23, 1969.
All documents filed by the Company pursuant to Section 13(a), 13(c), 14 or
15(d) of the Exchange Act subsequent to the date of this Prospectus and prior to
the termination of the offering of the Exchange Notes
134
<PAGE> 138
offered hereby shall be deemed to be incorporated by reference in this
Prospectus and to be part hereof from the date of filing of such documents. Any
statement contained in a document incorporated or deemed to be incorporated by
reference herein shall be deemed to be modified or superseded for purposes of
this Prospectus to the extent that a statement contained therein or in any other
subsequently filed document which also is or is deemed to be incorporated by
reference herein modifies or supersedes such statement. Any such statement so
modified or superseded shall not be deemed, except as so modified or superseded,
to constitute a part of this Prospectus.
The Company will provide without charge to each person, including any
beneficial owner of a Note, to whom a copy of this Prospectus is delivered, upon
written or oral request of such person, a copy of any or all documents
incorporated by reference in this Prospectus (other than exhibits to such
documents unless such exhibits are specifically incorporated by reference into
such documents). Requests for such copies should be directed to Tesoro Petroleum
Corporation, 8700 Tesoro Drive, San Antonio, Texas 78217-6218, Attention: Vice
President, Finance and Treasurer (telephone: (800) 837-6768).
Separate financial statements of the subsidiary Guarantors are not included
because the subsidiary Guarantors are jointly and severally liable and that the
aggregate net assets, earnings and equity of such Guarantors are substantially
equivalent to the net assets, earnings and equity of the parent on a
consolidated basis.
135
<PAGE> 139
INDEX TO FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
CONSOLIDATED FINANCIAL STATEMENTS OF TESORO PETROLEUM
CORPORATION
Independent Auditors' Report................................ F-2
Statements of Consolidated Operations -- Years Ended
December 31, 1995, 1996 and 1997 and Three Months Ended
March 31, 1997 and 1998................................... F-3
Consolidated Balance Sheets -- December 31, 1996 and 1997
and March 31, 1998........................................ F-4
Statements of Consolidated Stockholders' Equity -- Years
Ended December 31, 1995, 1996 and 1997 and Three Months
Ended March 31, 1998...................................... F-5
Statements of Consolidated Cash Flows -- Years Ended
December 31, 1995, 1996 and 1997 and Three Months Ended
March 31, 1997 and 1998................................... F-6
Notes to Consolidated Financial Statements.................. F-7
AUDITED COMBINED FINANCIAL STATEMENTS OF BHP PETROLEUM
AMERICAS REFINING INC. AND BHP PETROLEUM SOUTH PACIFIC
INC.
Report of Independent Public Accountants.................... F-37
Combined Statements of Operations -- Years Ended May 31,
1995, 1996 and 1997....................................... F-38
Combined Balance Sheets -- May 31, 1996 and 1997............ F-39
Combined Statements of Stockholders' Equity -- Years Ended
May 31, 1995, 1996 and 1997............................... F-40
Combined Statements of Cash Flows -- Years Ended May 31,
1995, 1996 and 1997....................................... F-41
Notes to Combined Financial Statements...................... F-42
UNAUDITED COMBINED FINANCIAL STATEMENTS OF BHP PETROLEUM
AMERICAS REFINING INC. AND BHP PETROLEUM SOUTH PACIFIC
INC.
Combined Statements of Operations -- Seven Months Ended
December 31, 1996 and 1997................................ F-54
Combined Balance Sheets -- December 31, 1996 and 1997....... F-55
Combined Statements of Cash Flows -- Seven Months Ended
December 31, 1996 and 1997................................ F-56
Notes to Combined Financial Statements...................... F-57
UNAUDITED COMBINED FINANCIAL STATEMENTS OF BHP PETROLEUM
AMERICAS REFINING INC. AND BHP PETROLEUM SOUTH PACIFIC
INC.
Combined Statements of Operations -- Ten Months Ended March
31, 1997 and 1998......................................... F-61
Combined Balance Sheets -- March 31, 1997 and 1998.......... F-62
Combined Statements of Cash Flows -- Ten Months Ended March
31, 1997 and 1998......................................... F-63
Notes to Combined Financial Statements...................... F-64
FINANCIAL STATEMENTS OF SHELL ANACORTES REFINING COMPANY
Report of Independent Accountants........................... F-68
Statement of Income -- Period from inception (January 4,
1996) through December 31, 1996 and the year ended
December 31, 1997 and the three months ended March 31,
1997 and 1998............................................. F-69
Consolidated Balance Sheet -- December 31, 1996 and 1997 and
March 31, 1998............................................ F-70
Statement of Shareholder's Equity -- Period from inception
(January 4, 1996) through December 31, 1996 and the year
ended December 31, 1997 and the three months ended March
31, 1998.................................................. F-71
Statement of Cash Flows -- Period from inception (January 4,
1996) through December 31, 1996 and the year ended
December 31, 1997 and the three months ended March 31,
1997 and 1998............................................. F-72
Notes to Financial Statements............................... F-73
</TABLE>
F-1
<PAGE> 140
INDEPENDENT AUDITORS' REPORT
Board of Directors and Stockholders
Tesoro Petroleum Corporation
We have audited the accompanying consolidated balance sheets of Tesoro
Petroleum Corporation and subsidiaries as of December 31, 1997 and 1996, and the
related statements of consolidated operations, stockholders' equity and cash
flows for each of the three years in the period ended December 31, 1997. These
financial statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in
all material respects, the financial position of Tesoro Petroleum Corporation
and subsidiaries at December 31, 1997 and 1996, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1997, in conformity with generally accepted accounting principles.
/s/ DELOITTE & TOUCHE LLP
San Antonio, Texas
January 28, 1998
F-2
<PAGE> 141
TESORO PETROLEUM CORPORATION
STATEMENTS OF CONSOLIDATED OPERATIONS
(IN THOUSANDS EXCEPT PER SHARE AMOUNTS)
<TABLE>
<CAPTION>
THREE MONTHS ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
---------------------------------- -------------------
1995 1996 1997 1997 1998
---------- ---------- -------- -------- --------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
REVENUES
Refining and marketing........................ $ 771,035 $ 745,413 $720,868 $174,400 $140,213
Exploration and production.................... 124,670 107,415 84,798 23,358 22,222
Marine services............................... 74,467 122,533 132,251 35,495 32,818
Income from settlement of a natural gas
contract.................................... -- 60,000 -- -- --
Gain on sale of assets and other income....... 32,711 4,417 5,543 1,599 786
---------- ---------- -------- -------- --------
Total Revenues......................... 1,002,883 1,039,778 943,460 234,852 196,039
---------- ---------- -------- -------- --------
OPERATING COSTS AND EXPENSES
Refining and marketing........................ 758,329 726,029 687,036 171,154 130,720
Exploration and production.................... 19,055 12,968 13,230 2,845 3,925
Marine services............................... 77,803 115,314 124,725 34,216 30,597
Depreciation, depletion and amortization...... 41,776 40,627 45,729 11,597 12,944
---------- ---------- -------- -------- --------
Total Operating Costs and Expenses..... 896,963 894,938 870,720 219,812 178,186
---------- ---------- -------- -------- --------
OPERATING PROFIT................................ 105,920 144,840 72,740 15,040 17,853
General and Administrative...................... (16,453) (12,733) (13,588) (3,038) (3,372)
Interest Expense, Net of Capitalized Interest in
1997.......................................... (20,902) (15,382) (6,699) (1,570) (2,665)
Interest Income................................. 1,845 8,423 1,597 434 108
Other Expense, Net.............................. (8,542) (10,001) (4,930) (1,291) (1,034)
---------- ---------- -------- -------- --------
EARNINGS BEFORE INCOME TAXES AND EXTRAORDINARY
ITEM.......................................... 61,868 115,147 49,120 9,575 10,890
Income Tax Provision............................ 4,379 38,347 18,435 3,444 4,831
---------- ---------- -------- -------- --------
EARNINGS BEFORE EXTRAORDINARY ITEM.............. 57,489 76,800 30,685 6,131 6,059
Extraordinary Loss on Extinguishments of Debt
(Net of Income Tax Benefit of $886 in 1996)... (2,857) (2,290) -- -- --
---------- ---------- -------- -------- --------
NET EARNINGS.................................... $ 54,632 $ 74,510 $ 30,685 $ 6,131 $ 6,059
========== ========== ======== ======== ========
NET EARNINGS PER SHARE -- BASIC................. $ 2.22 $ 2.87 $ 1.16 $ 0.23 $ 0.23
========== ========== ======== ======== ========
NET EARNINGS PER SHARE -- DILUTED............... $ 2.18 $ 2.81 $ 1.14 $ 0.23 $ 0.23
========== ========== ======== ======== ========
WEIGHTED AVERAGE COMMON SHARES -- BASIC......... 24,557 25,999 26,410 26,430 26,309
========== ========== ======== ======== ========
WEIGHTED AVERAGE COMMON SHARES AND POTENTIALLY
DILUTIVE COMMON SHARES -- DILUTED............. 25,107 26,499 26,868 26,829 26,789
========== ========== ======== ======== ========
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
F-3
<PAGE> 142
TESORO PETROLEUM CORPORATION
CONSOLIDATED BALANCE SHEETS
(DOLLARS IN THOUSANDS EXCEPT PER SHARE AMOUNTS)
<TABLE>
<CAPTION>
DECEMBER 31,
------------------- MARCH 31,
1996 1997 1998
-------- -------- -----------
(UNAUDITED)
<S> <C> <C> <C>
ASSETS
CURRENT ASSETS
Cash and cash equivalents................................. $ 22,796 $ 8,352 $ 2,274
Receivables, less allowance for doubtful accounts......... 128,013 76,282 64,518
Inventories............................................... 74,488 87,359 97,793
Prepayments and other..................................... 12,046 9,842 7,984
-------- -------- --------
Total Current Assets............................... 237,343 181,835 172,569
-------- -------- --------
PROPERTY, PLANT AND EQUIPMENT
Refining and marketing.................................... 328,522 370,174 368,183
Exploration and production, full-cost method of
accounting:
Properties being amortized.............................. 179,433 251,604 275,512
Properties not yet evaluated............................ 12,344 31,918 28,556
Gas transportation...................................... 6,703 7,889 7,804
Marine services........................................... 33,820 43,072 48,201
Corporate................................................. 12,531 13,689 13,802
-------- -------- --------
573,353 718,346 742,058
Less accumulated depreciation, depletion and
amortization.......................................... 256,842 304,523 317,645
-------- -------- --------
Net Property, Plant and Equipment.................. 316,511 413,823 424,413
-------- -------- --------
OTHER ASSETS................................................ 28,733 32,150 38,447
-------- -------- --------
Total Assets....................................... $582,587 $627,808 $635,429
======== ======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts payable.......................................... $ 80,747 $ 58,767 $ 44,275
Accrued liabilities....................................... 33,256 31,372 28,626
Current income taxes payable.............................. 13,822 354 1,627
Current maturities of long-term debt and other
obligations............................................. 10,043 17,002 11,428
-------- -------- --------
Total Current Liabilities.......................... 137,868 107,495 85,956
-------- -------- --------
DEFERRED INCOME TAXES....................................... 19,151 28,824 31,003
-------- -------- --------
OTHER LIABILITIES........................................... 42,243 43,211 42,821
-------- -------- --------
LONG-TERM DEBT AND OTHER OBLIGATIONS, LESS CURRENT
MATURITIES................................................ 79,260 115,314 136,290
-------- -------- --------
COMMITMENTS AND CONTINGENCIES (Notes K and L)
STOCKHOLDERS' EQUITY
Preferred stock, no par value; authorized 5,000,000 shares
including redeemable preferred shares; none issued or
outstanding
Common stock, par value $0.16 2/3; authorized 50,000,000
shares; 26,414,134, 26,506,601 and 26,515,868 shares
issued and outstanding, respectively.................... 4,402 4,418 4,419
Additional paid-in capital................................ 189,368 190,925 191,000
Retained earnings......................................... 110,295 140,980 147,039
Treasury stock, 200,198 common shares in 1998, at cost
(216,453 in 1997)....................................... -- (3,359) (3,099)
-------- -------- --------
Total Stockholders' Equity.............................. 304,065 332,964 339,359
-------- -------- --------
Total Liabilities and Stockholders' Equity......... $582,587 $627,808 $635,429
======== ======== ========
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
F-4
<PAGE> 143
TESORO PETROLEUM CORPORATION
STATEMENTS OF CONSOLIDATED STOCKHOLDERS' EQUITY
(INFORMATION FOR THE THREE-MONTH PERIOD ENDED MARCH 31, 1998 IS UNAUDITED)
(IN THOUSANDS)
<TABLE>
<CAPTION>
RETAINED
COMMON STOCK ADDITIONAL EARNINGS TREASURY STOCK
---------------- PAID-IN (ACCUMULATED ----------------
SHARES AMOUNT CAPITAL DEFICIT) SHARES AMOUNT
------- ------ ---------- ------------ ------ -------
<S> <C> <C> <C> <C> <C> <C>
BALANCE AT DECEMBER 31, 1994............... 24,390 $4,065 $175,514 $(18,847) -- $ --
Net earnings............................. -- -- -- 54,632 -- --
Shares issued pursuant to exercise of
stock options and stock awards........ 390 65 1,085 -- -- --
------- ------ -------- -------- ---- -------
BALANCE AT DECEMBER 31, 1995............... 24,780 4,130 176,599 35,785 -- --
Net earnings............................. -- -- -- 74,510 -- --
Issuance of Common Stock................. 1,308 218 11,054 -- -- --
Shares issued pursuant to exercise of
stock options and stock awards........ 326 54 1,715 -- -- --
------- ------ -------- -------- ---- -------
BALANCE AT DECEMBER 31, 1996............... 26,414 4,402 189,368 110,295 -- --
Net earnings............................. -- -- -- 30,685 -- --
Shares repurchased....................... -- -- -- -- (236) (3,701)
Shares issued pursuant to exercise of
stock options and stock awards and
employee benefit plans................ 45 7 440 -- 20 342
Other.................................... 48 9 1,117 -- -- --
------- ------ -------- -------- ---- -------
BALANCE AT DECEMBER 31, 1997............... 26,507 4,418 190,925 140,980 (216) (3,359)
Net earnings (unaudited)................. -- -- -- 6,059 -- --
Shares issued pursuant to exercise of
stock options and employee benefit
plans (unaudited)..................... 9 1 75 -- 16 260
------- ------ -------- -------- ---- -------
BALANCE AT MARCH 31, 1998 (unaudited)...... 26,516 $4,419 $191,000 $147,039 (200) $(3,099)
======= ====== ======== ======== ==== =======
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
F-5
<PAGE> 144
TESORO PETROLEUM CORPORATION
STATEMENTS OF CONSOLIDATED CASH FLOWS
(IN THOUSANDS)
<TABLE>
<CAPTION>
THREE MONTHS ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
--------------------------------- --------------------
1995 1996 1997 1997 1998
-------- -------- --------- -------- --------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
CASH FLOWS FROM (USED IN) OPERATING ACTIVITIES
Net earnings..................................... $ 54,632 $ 74,510 $ 30,685 $ 6,131 $ 6,059
Adjustments to reconcile net earnings to net cash
from operating activities:
Depreciation, depletion and amortization....... 42,620 41,459 46,363 11,747 13,154
Loss (gain) on sales of assets................. (32,659) 835 523 (18) (59)
Amortization of deferred charges and other..... 1,556 1,601 951 69 5
Extraordinary loss on extinguishments of debt,
net of income tax benefit.................... 2,857 2,290 -- -- --
Changes in operating assets and liabilities:
Receivables.................................. 9,746 (42,542) 56,785 43,533 11,764
Receivable from Tennessee Gas Pipeline
Company................................... (37,456) 50,680 -- -- --
Inventories.................................. (11,599) 7,210 (11,517) (3,089) (10,434)
Other assets................................. (3,573) (3,521) 296 3,487 1,691
Accounts payable and accrued liabilities..... 4,605 28,165 (37,854) (40,741) (15,980)
Deferred income taxes........................ 807 14,649 9,673 1,426 2,179
Obligation payments to State of Alaska....... (2,892) (4,047) (4,401) (1,064) (1,412)
Other liabilities and obligations............ 6,769 7,673 4,131 2,276 (530)
-------- -------- --------- -------- --------
Net cash from operating activities........ 35,413 178,962 95,635 23,757 6,437
-------- -------- --------- -------- --------
CASH FLOWS FROM (USED IN) INVESTING ACTIVITIES
Capital expenditures............................. (63,930) (84,957) (147,498) (16,300) (23,761)
Proceeds from sales of assets.................... 69,786 2,569 112 69 46
Deposits and other acquisition costs (Note C).... (3,029) (7,720) (5,086) -- (5,976)
Other............................................ (423) (4,092) 927 (548) 201
-------- -------- --------- -------- --------
Net cash from (used in) investing
activities.............................. 2,404 (94,200) (151,545) (16,779) (29,490)
-------- -------- --------- -------- --------
CASH FLOWS FROM (USED IN) FINANCING ACTIVITIES
Payments of long-term debt....................... (2,979) (3,838) (4,095) (764) (732)
Net borrowings under revolving credit
facilities..................................... -- 883 32,728 2,182 17,689
Issuance of long-term debt....................... -- -- 16,200 -- --
Repurchase of common stock....................... -- -- (3,701) -- --
Repurchase of debentures and notes............... (34,634) (74,116) -- -- --
Other............................................ (281) 1,164 334 171 18
-------- -------- --------- -------- --------
Net cash from (used in) financing
activities.............................. (37,894) (75,907) 41,466 1,589 16,975
-------- -------- --------- -------- --------
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS... (77) 8,855 (14,444) 8,567 (6,078)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD..... 14,018 13,941 22,796 22,796 8,352
-------- -------- --------- -------- --------
CASH AND CASH EQUIVALENTS, END OF PERIOD........... $ 13,941 $ 22,796 $ 8,352 $ 31,363 $ 2,274
======== ======== ========= ======== ========
SUPPLEMENTAL CASH FLOW DISCLOSURES
Interest paid, net of $419 capitalized in the
year 1997...................................... $ 18,132 $ 12,450 $ 2,127 $ 1,010 $ 1,706
======== ======== ========= ======== ========
Income taxes paid................................ $ 4,046 $ 6,285 $ 22,412 $ 14,245 $ 1,379
======== ======== ========= ======== ========
</TABLE>
The accompanying notes are an integral part of these consolidated financial
statements.
F-6
<PAGE> 145
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(INFORMATION FOR THE THREE-MONTH PERIODS ENDED MARCH 31, 1997 AND 1998 IS
UNAUDITED)
NOTE A -- SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The accompanying Consolidated Financial Statements include the accounts of
Tesoro Petroleum Corporation and its subsidiaries (collectively, the "Company"
or "Tesoro"). All significant intercompany accounts and transactions have been
eliminated. Tesoro is a natural resource company engaged in petroleum refining,
distributing and marketing of petroleum products, marine logistics services and
the exploration and production of natural gas and oil.
Use of Estimates and Presentation
The preparation of the Company's Consolidated Financial Statements in
conformity with generally accepted accounting principles 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.
Interim Reporting
The interim consolidated financial statements are unaudited but, in the
opinion of management, incorporate all adjustments necessary for a fair
presentation of the Company's financial position and results of operations for
such interim periods. Such adjustments are of a normal recurring nature. The
results of operations for any interim period are not necessarily indicative of
results for the full year.
Cash and Cash Equivalents
Cash equivalents consist of highly-liquid debt instruments such as
commercial paper and certificates of deposit purchased with an original maturity
date of three months or less. Cash equivalents are stated at cost, which
approximates market value. The Company's policy is to invest cash in
conservative, highly-rated instruments and to invest in various institutions to
limit the amount of credit exposure in any one institution. The Company performs
ongoing evaluations of the credit standing of these financial institutions.
Inventories
Inventories are stated at the lower of cost or market. The last-in,
first-out ("LIFO") method was used to determine the cost of the Company's
refining and marketing inventories of crude oil and U.S. wholesale refined
products. The cost of remaining refined product inventories, including fuel at
the Company's marine service terminals, was determined principally on the
first-in, first-out ("FIFO") method. Merchandise and materials and supplies are
valued at average cost, not in excess of market value. See Note F.
Property, Plant and Equipment
Additions to property, plant and equipment and major improvements and
modifications are capitalized at cost. Maintenance and repairs are charged to
operations when incurred. Depletion of oil and gas producing properties is
determined principally by the unit-of-production method and is based on
estimated recoverable reserves. Depreciation of other property, plant and
equipment is generally computed on the straight-line method based upon the
estimated useful life of each asset. The weighted average lives range from 12 to
30 years for refining, marketing and pipeline assets, 11 to 16 years for service
equipment and marine fleets, and five to seven years for corporate and other
assets.
F-7
<PAGE> 146
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Oil and gas properties are accounted for using the full-cost method of
accounting. Under this method, all costs associated with property acquisition
and exploration and development activities are capitalized into cost centers
that are established on a country-by-country basis. For each cost center, the
capitalized costs are subject to a limitation so as not to exceed the present
value of future net revenues from estimated production of proved oil and gas
reserves, net of income tax effect, plus the lower of cost or estimated fair
value of unproved properties included in the cost center. Capitalized costs
within a cost center, together with estimates of costs for future development,
dismantlement and abandonment, are amortized on a unit-of-production method
using the proved oil and gas reserves for each cost center. The Company's
investment in certain oil and gas properties is excluded from the amortization
base until the properties are evaluated. Gain or loss is recognized only on the
sale of oil and gas properties involving significant reserves. Proceeds from the
sale of insignificant reserves and undeveloped properties are applied to reduce
the costs in the cost centers.
Income Taxes
Deferred tax assets and liabilities are recognized for future income tax
consequences attributable to differences between financial statement carrying
amounts of assets and liabilities and their respective tax bases. Measurement of
deferred tax assets and liabilities is based on enacted tax rates expected to
apply to taxable income in the years in which those temporary differences are
expected to be recovered or settled. The effect on deferred tax assets and
liabilities of a change in tax rates is recognized in the period that includes
the enactment date.
Environmental Expenditures
Environmental expenditures that relate to current operations are expensed
or capitalized as appropriate. Expenditures that extend the life, increase the
capacity, or mitigate or prevent environmental contamination, are capitalized.
Expenditures that relate to an existing condition caused by past operations, and
which do not contribute to current or future revenue generation, are expensed.
Liabilities are recorded when environmental assessments and/or remedial efforts
are probable and the cost can be reasonably estimated. Such amounts are based on
the estimated timing and extent of remedial actions required by applicable
governing agencies, experience gained from similar sites on which environmental
assessments or remediation has been completed, and the amount of the Company's
anticipated liability considering the proportional liability and financial
abilities of other responsible parties. Generally, the timing of these accruals
coincides with completion of a feasibility study or the Company's commitment to
a formal plan of action. Estimated liabilities are not discounted to present
value.
Financial Instruments
The carrying amount of financial instruments including cash and cash
equivalents, accounts receivable, accounts payable and certain accrued
liabilities approximates fair value because of the short maturity of these
instruments. The carrying amount of the Company's long-term debt and other
obligations approximated the Company's estimates of the fair value of such
items.
F-8
<PAGE> 147
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Earnings Per Share
Earnings per share have been determined in accordance with Statement of
Financial Accounting Standard ("SFAS") No. 128 which establishes standards for
computing and presenting basic and diluted earnings per share calculations.
Basic earnings per share is determined by dividing net earnings by the weighted
average number of common shares outstanding during the period. The Company's
calculation of diluted earnings per share takes into account the effect of
potentially dilutive shares, principally stock options, outstanding during the
period. Prior period amounts have been restated to conform with the requirements
of SFAS No. 128. Earnings per share calculations are presented below (in
thousands except per share amounts):
<TABLE>
<CAPTION>
THREE MONTHS ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
--------------------------- -------------------
1995 1996 1997 1997 1998
------- ------- ------- -------- --------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
Earnings Applicable to Common
Shareholders (Basic and Diluted
Numerator):
Earnings before extraordinary item..... $57,489 $76,800 $30,685 $ 6,131 $ 6,059
Extraordinary loss on extinguishments
of debt, aftertax................... (2,857) (2,290) -- -- --
------- ------- ------- ------- -------
Net earnings........................ $54,632 $74,510 $30,685 $ 6,131 $ 6,059
======= ======= ======= ======= =======
Basic:
Weighted average common shares (Basic
denominator)........................ 24,557 25,999 26,410 26,430 26,309
======= ======= ======= ======= =======
Basic earnings per share --
Before extraordinary item........... $ 2.34 $ 2.96 $ 1.16 $ 0.23 $ 0.23
Extraordinary loss, aftertax........ (0.12) (0.09) -- -- --
------- ------- ------- ------- -------
Net................................. $ 2.22 $ 2.87 $ 1.16 $ 0.23 $ 0.23
======= ======= ======= ======= =======
Diluted:
Weighted average common shares......... 24,557 25,999 26,410 26,430 26,309
Incremental shares from assumed
conversion of stock options and
other............................... 550 500 458 399 480
------- ------- ------- ------- -------
Total diluted shares (Diluted
denominator).. 25,107 26,499 26,868 26,829 26,789
======= ======= ======= ======= =======
Diluted earnings per share --
Before extraordinary item........... $ 2.29 $ 2.90 $ 1.14 $ 0.23 $ 0.23
Extraordinary loss, aftertax........ (0.11) (0.09) -- -- --
------- ------- ------- ------- -------
Net................................. $ 2.18 $ 2.81 $ 1.14 $ 0.23 $ 0.23
======= ======= ======= ======= =======
</TABLE>
In accordance with SFAS No. 128, restricted Common Stock awards totaling
350,000 shares and options to purchase 340,000 shares of Common Stock under the
Company's special incentive compensation strategy (see Note K) were not included
in the computations of earnings per share in the years ended December 31, 1995,
1996 and 1997 and the three months ended March 31, 1997 and 1998. No shares were
issuable under this strategy during those periods since the attainment of a
specified market price of the Company's Common Stock had not been reached during
the periods presented. These awards and options remained outstanding at December
31, 1997 and March 31, 1998. See Note K regarding information related to the
vesting of these awards and options subsequent to March 31, 1998.
F-9
<PAGE> 148
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Stock-Based Compensation
The Company accounts for stock-based compensation using the intrinsic value
method prescribed in Accounting Principles Board ("APB") No. 25, "Accounting for
Stock Issued to Employees," and related interpretations. Accordingly,
compensation cost for stock options is measured as the excess, if any, of the
quoted market price of the Company's Common Stock at the date of grant over the
amount an employee must pay to acquire the stock. The Company has adopted the
disclosure requirements of SFAS No. 123, "Accounting for Stock-Based
Compensation," as included in Note K.
New Accounting Standards
In June 1997, the FASB issued SFAS No. 131, "Disclosures about Segments of
an Enterprise and Related Information," which establishes standards for
reporting information about operating segments in annual financial statements
and requires that selected information about operating segments be included in
interim financial reports issued to shareholders. SFAS No. 131 also establishes
standards for related disclosures about products and services, geographic areas
and major customers. SFAS No. 131 becomes effective for the Company's 1998
year-end and need not be applied to interim financial information until 1999. In
February 1998, the FASB issued SFAS No. 132, "Employers' Disclosures about
Pensions and Other Postretirement Benefits," which standardizes the disclosures
related to pensions and other postretirement benefits to the extent practicable,
requires additional information on changes in the benefit obligations and fair
values of plan assets and eliminates certain disclosures previously required.
SFAS No. 132 becomes effective for the Company in 1998. Both statements contain
provisions for restatement of prior period information. The Company is
evaluating the effects that these new statements will have on its financial
reporting and disclosures. The new statements will have no effect on the
Company's results of operations, financial position or cash flows.
The Company adopted SFAS No. 130, "Reporting Comprehensive Income," which
establishes standards for reporting and display of comprehensive income
effective January 1, 1998. There are no material differences between net
earnings and comprehensive income for all periods presented.
NOTE B -- BUSINESS SEGMENTS
The Company's revenues are derived from three business segments: Refining
and Marketing, Exploration and Production, and Marine Services.
Refining and Marketing operates a petroleum refinery at Kenai, Alaska,
which manufactures gasoline, jet fuel, diesel fuel, heavy oils and residual
products. These products, together with products purchased from third parties,
are sold at wholesale through terminal facilities and other locations in Alaska
and the Pacific Northwest. In addition, Refining and Marketing markets gasoline,
other petroleum products and convenience store items at retail through 35
Company-operated stations in Alaska. Refining and Marketing also markets
petroleum products through 129 branded and 28 unbranded stations located in
Alaska and the Pacific Northwest. Revenues from export sales, primarily to Far
East markets, amounted to $18.5 million, $22.0 million and $16.1 million in the
year ended December 31, 1995, 1996 and 1997, respectively, and $6.7 million and
$5.9 million in the three months ended March 31, 1997 and 1998, respectively.
The Company at times resells previously purchased crude oil, sales of which
amounted to $75.8 million, $93.8 million and $44.4 million in the years ended
December 31, 1995, 1996 and 1997, respectively, and $10.7 million and $10.5
million in the three months ended March 31, 1997 and 1998, respectively. For
information related to refining and marketing operations in Hawaii which were
acquired in May 1998, see Note C.
The Exploration and Production segment is engaged in the exploration,
production and development of natural gas and oil onshore in Texas, Louisiana
and Bolivia. This segment also includes the transportation of natural gas,
including the Company's production, to common carrier pipelines in South Texas.
In Bolivia, the
F-10
<PAGE> 149
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Company operates under four contracts with the Bolivian government to explore
for and produce hydrocarbons. The Company's Bolivian natural gas production is
sold under contract to the Bolivian government for export to Argentina. The
majority of the Company's Bolivian natural gas and oil reserves are shut-in
awaiting access to gas-consuming markets. Major developments in South America
indicate that new markets may open for the Company's production in the near
future. Construction of a new 1,900-mile pipeline that will link Bolivia's gas
reserves with markets in Brazil commenced in 1997 and is expected to be
operational in early 1999.
Marine Services markets and distributes petroleum products and provides
logistics services, primarily to the marine and offshore exploration and
production industries operating in the Gulf of Mexico. This segment currently
operates through 20 terminals along the Texas and Louisiana Gulf Coast and three
terminals on the U.S. West Coast.
Segment operating profit is gross operating revenues, gains and losses on
asset sales and other income less applicable segment costs of sales, operating
expenses, depreciation, depletion and other items. Income taxes, interest
expense, interest income and corporate general and administrative expenses are
not included in determining operating profit. In the Exploration and Production
segment, operating profit in the year ended December 31, 1997 included income of
$1.8 million for severance tax refunds and $2.2 million related to the
collection of a receivable for prior years Bolivian production. Operating profit
in the Exploration and Production segment in the year ended December 31, 1996
included $60 million of income from termination of a natural gas contract and $5
million for retroactive severance tax refunds, and the year ended December 31,
1995 included a gain of $33 million from the sale of certain interests in the
Bob West Field. In the years ended December 31, 1995 and 1996, the Exploration
and Production segment's operating profit included $47.1 million and $24.6
million, respectively, from the excess of natural gas contract prices over spot
market prices (see Note D).
Identifiable assets are those assets utilized by the segment. Corporate
assets are principally cash, investments and other assets that cannot be
directly associated with the operations of a business segment. Segment
information is as follows (in millions):
<TABLE>
<CAPTION>
THREE MONTHS
ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
---------------------------- ---------------
1995 1996 1997 1997 1998
-------- -------- ------ ------ ------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
REVENUES
Gross operating revenues:
Refining and Marketing --
Refined products............................ $ 664.5 $ 620.8 $643.7 $155.8 $122.7
Other, primarily crude oil resales and
merchandise.............................. 106.5 124.6 77.2 18.6 17.5
Exploration and Production --
U.S., including gas transportation.......... 113.0 93.8 73.6 21.5 19.1
Bolivia..................................... 11.7 13.7 11.2 1.9 3.1
Marine Services............................... 74.5 122.5 132.2 35.5 32.8
-------- -------- ------ ------ ------
Total Gross Operating Revenues.............. 970.2 975.4 937.9 233.3 195.2
Income from settlement of a natural gas contract
and other..................................... 32.7 64.4 5.5 1.6 0.8
-------- -------- ------ ------ ------
Total Revenues........................... $1,002.9 $1,039.8 $943.4 $234.9 $196.0
======== ======== ====== ====== ======
</TABLE>
F-11
<PAGE> 150
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
THREE MONTHS
ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
---------------------------- ---------------
1995 1996 1997 1997 1998
-------- -------- ------ ------ ------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
OPERATING PROFIT (LOSS)
Refining and Marketing.......................... $ 0.7 $ 6.0 $ 20.5 $ 0.1 $ 6.5
Exploration and Production --
U.S., including gas transportation............ 102.0 123.9 37.3 13.0 7.9
Bolivia....................................... 7.6 8.8 8.6 1.0 1.7
Marine Services................................. (4.4) 6.1 6.3 0.9 1.8
-------- -------- ------ ------ ------
Total Operating Profit................... 105.9 144.8 72.7 15.0 17.9
Corporate and Unallocated Costs................. (44.0) (29.7) (23.6) (5.4) (7.0)
-------- -------- ------ ------ ------
Earnings Before Income Taxes and Extraordinary
Item.......................................... $ 61.9 $ 115.1 $ 49.1 $ 9.6 $ 10.9
======== ======== ====== ====== ======
IDENTIFIABLE ASSETS
Refining and Marketing.......................... $ 313.3 $ 317.0 $337.4 $298.6 $333.2
Exploration and Production --
U.S., including gas transportation............ 136.7 143.6 158.2 121.2 165.6
Bolivia....................................... 17.8 27.0 50.8 28.2 51.4
Marine Services................................. 18.0 56.0 59.3 55.9 60.6
Corporate....................................... 33.4 39.0 22.1 48.1 24.6
-------- -------- ------ ------ ------
Total Assets............................. $ 519.2 $ 582.6 $627.8 $552.0 $635.4
======== ======== ====== ====== ======
DEPRECIATION, DEPLETION AND AMORTIZATION
Refining and Marketing.......................... $ 11.9 $ 12.5 $ 12.7 $ 3.1 $ 3.0
Exploration and Production --
U.S., including gas transportation............ 29.3 25.6 29.8 7.9 8.9
Bolivia....................................... 0.3 1.3 1.5 0.2 0.5
Marine Services................................. 0.3 1.2 1.7 0.4 0.6
Corporate....................................... 0.8 0.9 0.7 0.1 0.2
-------- -------- ------ ------ ------
Total Depreciation, Depletion and
Amortization........................... $ 42.6 $ 41.5 $ 46.4 $ 11.7 $ 13.2
======== ======== ====== ====== ======
CAPITAL EXPENDITURES
Refining and Marketing.......................... $ 9.3 $ 11.1 $ 43.9 $ 2.9 $ 2.0
Exploration and Production --
U.S., including gas transportation............ 49.6 59.7 65.4 7.0 18.2
Bolivia....................................... 3.8 6.9 27.5 4.0 2.3
Marine Services................................. 0.4 6.9 9.4 2.2 1.2
Corporate....................................... 0.8 0.4 1.3 0.2 0.1
-------- -------- ------ ------ ------
Total Capital Expenditures............... $ 63.9 $ 85.0 $147.5 $ 16.3 $ 23.8
======== ======== ====== ====== ======
</TABLE>
NOTE C -- ACQUISITIONS, EXPANSIONS AND DIVESTITURES
Hawaii Refinery Acquisition
On March 18, 1998, the Company entered into a stock sale agreement ("Hawaii
Stock Sale Agreement") with BHP Hawaii Inc. and BHP Petroleum Pacific Islands
Inc. (collectively, the "Sellers"), subsidiaries of The Broken Hill Proprietary
Company Limited ("BHP"), whereby Tesoro purchased (the "Hawaii Acquisition") all
of the outstanding stock of BHP Petroleum Americas Refining Inc. ("BHP
Refining") and BHP Petroleum South Pacific Inc. ("BHP South Pacific"). The
primary assets of BHP Refining and BHP South Pacific include a 95,000-barrel per
day refinery and 32 retail gasoline stations located
F-12
<PAGE> 151
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
in Hawaii. In addition, Tesoro and a BHP affiliate entered into a two-year crude
supply agreement pursuant to which the BHP affiliate will assist Tesoro in
acquiring crude oil feedstock sourced outside of North America and arrange for
the transportation of such crude oil to the Hawaii refinery.
The Hawaii Acquisition closed effective May 31, 1998. Tesoro paid $243.5
million in cash for the Hawaii Acquisition, including $5 million that was
deposited into an escrow account in March 1998 and $68.5 million for estimated
net working capital. The cash purchase price is subject to post-closing
adjustments. In addition, Tesoro issued an unsecured, non-interest bearing,
promissory note for the purchase in the amount of $50 million, payable in five
equal annual installments of $10 million each, beginning in 2009. The note
provides for early payment to the extent of one-half of the amount by which
earnings from the acquired assets, before interest expense, income taxes and
depreciation, depletion and amortization, as specified in the note, exceed $50
million in any calendar year. The Hawaii Acquisition will be accounted for as a
purchase whereby the purchase price will be allocated to the assets acquired and
liabilities assumed based on their estimated fair values at the date of
acquisition.
Washington State Refinery Acquisition
On May 1, 1998, the Company entered into a stock purchase agreement
("Anacortes Stock Purchase Agreement") with Shell Refining Holding Company
("Seller") and Shell Anacortes Refining Company ("SARC"), both subsidiaries of
Shell Oil Company ("Shell"), whereby Tesoro will purchase (the "Washington
Acquisition") all of the outstanding stock of SARC. SARC owns and operates a
108,000-barrel per day refinery in Anacortes, Washington ("Washington
Refinery"). The Washington Acquisition, which is subject to approval by the
Federal Trade Commission and the offices of the attorneys general of the States
of Oregon and Washington as well as of other customary conditions, is
anticipated to close in mid to late summer. Under the terms of the Anacortes
Stock Purchase Agreement, the Company paid a $5 million deposit in May 1998 and
has subsequently escrowed $266.9 million for the purchase price.
At closing, the Company will pay the Seller a cash purchase price of $237
million, less the deposit and any escrowed amounts, for the stock of SARC, and
will also pay an additional amount for net working capital of SARC which has
historically averaged approximately $60 million.
See Note I for information related to financings of the Hawaii Acquisition
and proposed Washington Acquisition (collectively, the "Acquisitions") and Note
L for related environmental matters.
Alaska Refining and Marketing
In October 1997, the Company completed an expansion of its refinery
hydrocracker unit which enables the Company to increase its jet fuel production.
The expansion, together with the addition of a new, high-yield jet fuel
hydrocracker catalyst, was completed at a cost of approximately $19 million. For
information on financing of this expansion, see Note I.
In December 1997, the Refining and Marketing segment purchased the Union 76
marketing assets in Southeast Alaska, consisting of one terminal, two retail
stations and the rights to use the Union 76 trademark within Alaska. The Company
also expanded its Alaskan retail operations throughout the year with
construction of two new facilities and remodeling of three existing stations.
Two uneconomic outlets in Alaska were closed in the year ended December 31,
1997.
Exploration and Production
In July 1997, the Company purchased the interests held by its former joint
venture participant in the then existing two contract blocks in southern
Bolivia, consisting of a 25% interest in Block 18 and a 27.4% interest in Block
20. The purchase price was approximately $20 million, which included $11.9
million for proved
F-13
<PAGE> 152
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
reserves and $3.4 million for undeveloped acreage with the remainder for working
capital and assumption of certain liabilities.
In the U.S., the Exploration and Production segment purchased proved and
unproved properties totaling $22 million during the year ended December 31,
1997. These purchases included the acquisition of interests in the Kent Bayou
Field in Terrebonne Parish in southern Louisiana for $5 million and interests in
the La Blanca, San Salvador and San Carlos Fields in the Frio/Vicksburg Trend of
Hildago County in South Texas for $3.1 million during November 1997. Also
included was the acquisition of interests in three natural gas fields in East
Texas, including the Carthage Field in Panola County, the Woodlawn Field in
Harrison County and the Oak Hill Field in Rusk County, for $5.1 million in
December 1997.
During the year ended December 31, 1996, the Company's Exploration and
Production segment recorded acquisitions of proved and unproved properties
totaling $25.7 million. The most significant of these was the purchase in
December 1996 of interests in the Los Indios and La Reforma Fields, located in
Hidalgo and Starr counties of South Texas, for $15 million. These two fields are
in the Frio/Vicksburg Trend, which lies immediately adjacent to the Wilcox
Trend. Other acquisitions in the year ended December 31, 1996 included the
purchase of interests in the Berry R. Cox and the West Goliad Fields, both
located in the Wilcox Trend, for $5.4 million and the purchase of acreage in
East Texas for $5.3 million.
In September 1995, the Company sold, effective April 1, 1995, certain
interests in its producing and non-producing oil and gas properties located in
the Bob West Field in South Texas. The interests sold included the Company's
approximate 55% net revenue interest and 70% working interest in Units C, D and
E and a convertible override in Unit F of the Bob West Field. Excluded from the
sale were the Company's interests in the State Park and Sanchez-O'Brien leases
and the Ramirez USA E-6 well within the Bob West Field. In total, the sale
included interests in 14 gross producing wells amounting to 77 Bcf, or 40%, of
the Company's total net proved domestic reserves at the time of the sale (see
Note N). For the year ended December 31, 1995, natural gas production from the
interests sold had contributed approximately $11.7 million to revenues and $4
million to operating profit in the Company's Exploration and Production segment.
Consideration for the sale was $74 million, which was adjusted for production,
capital expenditures and certain other items after the effective date to
approximately $68 million in cash received at closing, resulting in a gain of
approximately $33 million in the 1995 third quarter. The consideration received
by the Company was used to redeem $34.6 million of the Company's outstanding
12 3/4% Subordinated Debentures in the year ended December 31, 1995, reduce
borrowings under the Company's revolving credit facility and improve corporate
liquidity (see Note I).
For further information related to exploration and production activities,
see Note N.
Marine Services
In February 1996, the Company purchased 100% of the capital stock of
Coastwide Energy Services, Inc. ("Coastwide"). The consideration included
approximately 1.4 million shares of Tesoro's Common Stock and $7.7 million in
cash. The market price of Tesoro's Common Stock was $9.00 per share at closing
of this transaction. In addition, Tesoro repaid approximately $4.5 million of
Coastwide's outstanding debt. Coastwide was primarily a provider of logistical
support services and a distributor of petroleum products to the offshore oil and
gas industry in the Gulf of Mexico. The Company combined the Coastwide operation
with its marine petroleum distribution operations, forming a Marine Services
segment. The acquisition was accounted for as a purchase whereby the purchase
price was allocated to the assets acquired and liabilities assumed based upon
their estimated fair values.
F-14
<PAGE> 153
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
NOTE D -- GAS PURCHASE AND SALES CONTRACT
Resolution of Litigation in 1996
On August 16, 1996, the Supreme Court of Texas issued a mandate that denied
a motion for rehearing by Tennessee Gas Pipeline Company ("Tennessee Gas") and
upheld all aspects of a Gas Purchase and Sales Agreement ("Tennessee Gas
Contract") which had been the subject of litigation since 1990. As provided for
in the Tennessee Gas Contract, the Company was selling a portion of the gas
produced from the Bob West Field to Tennessee Gas at a maximum price as
calculated in accordance with Section 102(b)(2) ("Contract Price") of the
Natural Gas Policy Act of 1978. Subsequent to the mandate, the Company received
cash of $67.7 million from Tennessee Gas, which included collection of a $59.6
million bonded receivable for underpayment for natural gas sold in prior
periods. The remaining $8.1 million received was for interest and reimbursement
of legal fees and court costs, which resulted in income during the 1996 third
quarter. Tennessee Gas resumed paying the Contract Price to the Company for gas
taken beginning with May 1996 volumes up until termination of the Tennessee Gas
Contract discussed below.
Settlement and Termination of Contract in 1996
On December 24, 1996, the Company settled all other claims and disputes
with Tennessee Gas, including litigation in Zapata County, Texas filed by
Tennessee Gas, and agreed to terminate the Tennessee Gas Contract effective
October 1, 1996. The Tennessee Gas Contract would have extended through January
1999. Under the settlement, the Company received $51.8 million and the right to
recover severance taxes paid by Tennessee Gas of approximately $8.2 million,
which resulted in income of $60 million to the Company during the 1996 fourth
quarter. The severance taxes were subsequently collected in the year ended
December 31, 1997.
NOTE E -- RECEIVABLES
Concentrations of credit risk with respect to accounts receivable are
limited, due to the large number of customers comprising the Company's customer
base and their dispersion across the Company's industry segments and geographic
areas of operations. The Company performs ongoing credit evaluations of its
customers' financial condition and in certain circumstances requires letters of
credit or other collateral arrangements. The Company's allowance for doubtful
accounts is reflected as a reduction of receivables in the Consolidated Balance
Sheets. The following table reconciles the change in the Company's allowance for
doubtful accounts (in thousands):
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED
------------------------ MARCH 31,
1995 1996 1997 1998
------ ------ ------ ------------
(UNAUDITED)
<S> <C> <C> <C> <C>
Balance at Beginning of Year................... $1,816 $1,842 $1,515 $1,373
Charged to Costs and Expenses.................. 300 589 23 10
Recoveries of Amounts Previously Written Off
and Other.................................... 122 (44) 189 37
Write-off of Doubtful Accounts................. (396) (872) (354) (128)
------ ------ ------ ------
Balance at End of Year....................... $1,842 $1,515 $1,373 $1,292
====== ====== ====== ======
</TABLE>
F-15
<PAGE> 154
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
NOTE F -- INVENTORIES
Components of inventories were as follows (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
------------------ MARCH 31,
1996 1997 1998
------- ------- -----------
(UNAUDITED)
<S> <C> <C> <C>
Crude Oil and Wholesale Refined Products, at LIFO... $55,858 $68,227 $75,983
Merchandise and Other Refined Products.............. 13,539 13,377 14,424
Materials and Supplies.............................. 5,091 5,755 7,386
------- ------- -------
Total Inventories................................. $74,488 $87,359 $97,793
======= ======= =======
</TABLE>
At December 31, 1996 and 1997, inventories valued using LIFO were lower
than replacement cost by approximately $17.7 million and $4.4 million,
respectively.
NOTE G -- ACCRUED LIABILITIES
The Company's current accrued liabilities and noncurrent other liabilities
as shown in the Consolidated Balance Sheets included the following (in
thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
------------------ MARCH 31,
1996 1997 1998
------- ------- -----------
(UNAUDITED)
<S> <C> <C> <C>
Accrued Liabilities -- Current:
Accrued environmental costs....................... $ 5,367 $ 5,817 $ 6,199
Accrued employee costs............................ 7,759 12,406 9,014
Accrued taxes other than income taxes............. 5,988 4,137 2,783
Accrued interest.................................. 1,155 1,349 1,126
Other............................................. 12,987 7,663 9,504
------- ------- -------
Total Accrued Liabilities -- Current........... $33,256 $31,372 $28,626
======= ======= =======
Other Liabilities -- Noncurrent:
Accrued postretirement benefits................... $30,508 $32,206 $32,695
Accrued environmental costs....................... 3,496 2,659 2,489
Other............................................. 8,239 8,346 7,637
------- ------- -------
Total Other Liabilities -- Noncurrent.......... $42,243 $43,211 $42,821
======= ======= =======
</TABLE>
NOTE H -- INCOME TAXES
The income tax provision included the following (in thousands):
<TABLE>
<CAPTION>
THREE MONTHS ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
----------------------------- ------------------
1995 1996 1997 1997 1998
------- ------- ------- ------- -------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
Federal -- Current................. $ 708 $16,206 $ 3,413 $1,197 $1,209
Federal -- Deferred................ -- 17,405 9,421 1,254 1,569
Foreign............................ 3,183 3,654 4,920 744 1,378
State.............................. 488 1,082 681 249 675
------- ------- ------- ------ ------
Income Tax Provision............. $ 4,379 $38,347 $18,435 $3,444 $4,831
======= ======= ======= ====== ======
</TABLE>
F-16
<PAGE> 155
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Deferred income taxes and benefits are provided for differences between
financial statement carrying amounts of assets and liabilities and their
respective tax bases. Temporary differences and the resulting deferred tax
assets and liabilities are summarized as follows (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
-------------------- MARCH 31,
1996 1997 1998
-------- -------- -----------
(UNAUDITED)
<S> <C> <C> <C>
Deferred Federal Tax Assets:
Investment tax and other credits.................. $ 11,962 $ 9,639 $ 9,039
Accrued postretirement benefits................... 9,941 10,480 10,688
Settlement with Department of Energy.............. 3,694 3,233 2,771
Environmental reserve............................. 3,335 3,048 2,901
Other............................................. 1,523 5,265 5,523
-------- -------- --------
Total Deferred Federal Tax Assets.............. 30,455 31,665 30,922
Deferred Federal Tax Liabilities:
Accelerated depreciation and property-related
items.......................................... 47,147 57,778 58,604
-------- -------- --------
Net Deferred Federal Liability...................... 16,692 26,113 27,682
State Income and Other Taxes........................ 2,459 2,711 3,321
-------- -------- --------
Net Deferred Tax Liability........................ $ 19,151 $ 28,824 $ 31,003
======== ======== ========
</TABLE>
The following tables set forth the components of the Company's results of
operations (in thousands) and a reconciliation of the normal statutory federal
income tax rate with the Company's effective tax rate:
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
----------------------------- ----------------
1995 1996 1997 1997 1998
-------- -------- ------- ------ -------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
Earnings Before Income Taxes and
Extraordinary Item:
U.S............................... $ 55,221 $106,675 $40,200 $8,804 $ 8,669
Foreign........................... 6,647 8,472 8,920 771 2,221
-------- -------- ------- ------ -------
Total Earnings Before Income
Taxes and Extraordinary
Item......................... $ 61,868 $115,147 $49,120 $9,575 $10,890
======== ======== ======= ====== =======
Statutory U.S. Corporate Tax Rate... 35% 35% 35% 35% 35%
Effect of:
Foreign income taxes, net of tax
benefit........................ 5 2 5 3 6
State income taxes, net of tax
benefit........................ 1 1 1 3 4
Accounting recognition of
operating loss tax benefits.... (33) (4) -- -- --
Other............................. (1) (1) (4) (5) (1)
-------- -------- ------- ------ -------
Effective Income Tax Rate........... 7% 33% 37% 36% 44%
======== ======== ======= ====== =======
</TABLE>
At December 31, 1997, the Company had approximately $6.9 million of
investment tax credits and employee stock ownership credits available for
carryover to subsequent years, which, if not used, will expire in the years 1999
through 2006. Additionally, at December 31, 1997, the Company had approximately
$2.7 million of alternative minimum tax credit carryforwards, with no expiration
dates, to offset future regular tax liabilities.
F-17
<PAGE> 156
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
NOTE I -- LONG-TERM DEBT AND OTHER OBLIGATIONS
Long-term debt and other obligations consisted of the following (in
thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
------------------ MARCH 31,
1996 1997 1998
------- -------- -----------
(UNAUDITED)
<S> <C> <C> <C>
Liability to State of Alaska.......................... $62,079 $ 62,016 $ 61,780
Corporate Revolving Credit Facility................... -- 28,000 51,300
Marine Services Loan Facility......................... 883 5,611 --
Hydrocracker Loan..................................... -- 16,200 16,200
Vacuum Unit Loan...................................... 11,250 9,107 8,572
Liability to Department of Energy..................... 10,555 9,235 7,916
Other................................................. 4,536 2,147 1,950
------- -------- --------
89,303 132,316 147,718
Less Current Maturities............................... 10,043 17,002 11,428
------- -------- --------
$79,260 $115,314 $136,290
======= ======== ========
</TABLE>
Aggregate maturities of long-term debt and obligations for each of the five
years following December 31, 1997 are as follows: 1998 -- $17.0 million;
1999 -- $11.9 million; 2000 -- $40.1 million; 2001 -- $13.6 million; and
2002 -- $5.6 million.
On May 4, 1998, the Company filed a universal shelf registration statement
("Registration Statement") with the Securities and Exchange Commission ("SEC")
for $600 million of debt or equity securities for acquisitions or general
corporate purposes. The Registration Statement was declared effective by the SEC
on May 14, 1998. The Company offered Common Stock and Premium Income Equity
Securities ("PIES") from the Registration Statement to provide partial funding
for the Acquisitions discussed in Note C. In July 1998, the Company issued
5,750,000 shares of Common Stock with gross proceeds of approximately $91.6
million and 10,350,000 PIES, representing fractional interests in shares of
7.25% Mandatorily Convertible Preferred Stock, with gross proceeds of
approximately $164.9 million. The PIES will pay a cash dividend and are
mandatorily convertible into shares of Common Stock based upon a formula
dependent upon the market price of Common Stock.
In addition to the offerings of Common Stock and PIES, on July 2, 1998, the
Company issued $300 million in notes ("Senior Subordinated Notes") through a
private offering eligible for Rule 144A. The Senior Subordinated Notes have a
ten-year maturity without sinking fund requirements and are subject to optional
redemption by the Company after five years at declining premiums.
In conjunction with closing the Hawaii Acquisition (see Note C), on May 29,
1998, the Company refinanced substantially all of its existing indebtedness (the
"Refinancing") using revolving credit and term loans through an amended and
restated credit facility (the "Interim Credit Facility") provided by Lehman
Commercial Paper, Inc. ("LCPI"). The total amount of funds required by Tesoro to
complete the Hawaii Acquisition and the Refinancing, to pay related fees and
expenses, and for general corporate purposes was approximately $432 million.
Subsequent to June 30, 1998, the Company refinanced all borrowings under the
Interim Credit Facility with net proceeds from offerings of Common Stock and
PIES and borrowings under a new senior secured credit facility ("Senior Credit
Facility"). The Company entered into the Senior Credit Facility with a group of
lenders led by LCPI on July 2, 1998. The Senior Credit Facility is in the total
amount of $500 million, comprised of term loan facilities aggregating $200
million (two $100 million tranches) and a $300 million revolving credit
facility. The Senior Credit Facility is guaranteed by substantially all of the
Company's active direct and indirect subsidiaries (the "Guarantors") and is
secured by substantially all of the domestic assets of the Company and each of
the Guarantors. The Senior Credit Facility replaces the Interim Credit Facility.
In addition to funding the cash consideration of the Acquisitions and
Refinancing, the Senior
F-18
<PAGE> 157
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Credit Facility will provide the Company with increased letter of credit
capacity and funds for future working capital needs and general corporate
purposes, including the Company's 1998 capital budget. The Company will record
an extraordinary loss on early extinguishment of debt of approximately $5
million, net of income tax benefit, for the Refinancing during the second
quarter of 1998.
Former Corporate Revolving Credit Facility
Prior to May 29, 1998, the Company's amended and restated corporate
revolving credit agreement ("Former Credit Facility"), which was replaced by the
Interim Facility and Senior Credit Facility, provided total commitments of $150
million from a consortium of nine banks. The Company, at its option, had
activated $100 million of these commitments. The Credit Facility provided for
the issuance of letters of credit, and for cash borrowings up to $100 million,
with the aggregate subject to a borrowing base (which amount exceeded total
commitments at December 31, 1997). Outstanding obligations under the Credit
Facility were collateralized by first liens on substantially all of the
Company's trade receivables, product inventories and South Texas natural gas
reserves and by a third lien on the Company's refinery.
At December 31, 1997, the Company had outstanding cash borrowings of $28
million under the Former Credit Facility. During 1997, gross borrowings under
the Former Credit Facility were $150 million, with $122 million of repayments.
During 1995 and 1996, the Company's gross borrowings equaled repayments under
the Credit Facility and totaled $262 million and $165 million, respectively.
These cash borrowings were generally used on a short-term basis to finance
working capital requirements and capital expenditures. Under the Former Credit
Facility, at December 31, 1997, the Company had outstanding letters of credit of
$34 million, primarily for royalty crude oil purchases from the State of Alaska.
Unused availability, including unactivated commitments, under the Former Credit
Facility at December 31, 1997 for additional borrowings and letters of credit
totaled $88 million. The Company was also permitted to utilize unsecured letters
of credit outside of the Former Credit Facility up to $40 million (none
outstanding at December 31, 1997).
Cash borrowings under the Former Credit Facility incurred interest at (i)
the London Interbank Offered Rate ("LIBOR") plus 1.0% per annum or (ii) the
prime rate per annum, at the Company's option. Fees on outstanding letters of
credit under the Credit Facility were 1.0% per annum.
State of Alaska
In 1993, the Company entered into an agreement ("Agreement") with the State
of Alaska ("State") that settled a contractual dispute with the State. Under the
Agreement, the Company was obligated to make variable monthly payments to the
State through December 2001 based on a per barrel charge on the volume of
feedstock processed through the Company's Alaska refinery crude unit. In the
year ended December 31, 1995, based on a per barrel throughput charge of 16
cents, the Company's variable payments to the State totaled $2.9 million. In the
years ended December 31, 1996 and 1997, based on a per barrel throughput charge
of 24 cents, the Company's variable payments to the State totaled $4.0 million
and $4.4 million, respectively. In the three months ended March 31, 1998, based
on a per barrel throughput charge of 30 cents, the Company's variable payments
to the State totaled $1.4 million. The per barrel charge increased to 30 cents
in 1998 with one cent annual incremental increases thereafter through 2001. The
Agreement obligated the Company to pay the State $60 million in January 2002;
provided, however, that such payment could be deferred indefinitely, at the
Company's option, by continuing the variable monthly payments to the State
beginning at 34 cents per barrel for 2002 and increasing one cent per barrel
annually thereafter. Under the Agreement, variable monthly payments made after
January 2002 would not reduce the $60 million obligation to the State. The
imputed rate of interest used by the Company on the $60 million obligation was
13%.
On May 29, 1998, the State released the Company from all payment
obligations, and all mortgages, liens and security interests in connection
therewith, under the Agreement in exchange for a payment of $66.1 million. The
Company is only obligated to continue payment of the per barrel throughput
charge
F-19
<PAGE> 158
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
through 2001 with respect to barrels of feedstock processed at the refinery
which exceed 50,000 barrels per day on a monthly basis, subject to a credit for
an amount by which the barrels of feedstock processed after June 1, 1998 average
less than 50,000 barrels per day on a monthly basis.
Marine Services Loan Facility
In January 1998, the Company terminated a $10 million loan facility which
had provided a three-year line of credit to the Marine Services segment at the
bank's prime rate. The outstanding balance of $5.6 million at December 31, 1997
was repaid and terminated in January 1998.
Hydrocracker Loan
In October 1997, the National Bank of Alaska ("NBA") and the Alaska
Industrial Development and Export Authority ("AIDEA"), under a loan agreement
("Hydrocracker Loan") entered into between the Company and NBA, provided a $16.2
million loan to the Company towards the cost of its refinery hydrocracker
expansion (see Note C). One-half of the loan was funded by NBA and the other
half was funded by AIDEA. The Hydrocracker Loan which was to mature on or before
April 1, 2005 and required 28 equal quarterly principal payments beginning April
1998 together with interest at the unsecured 90-day commercial paper rate (5.55%
at December 31, 1997) adjusted quarterly plus (i) 2.6% per annum on 50% of the
amount borrowed and (ii) 2.35% per annum on the other 50% borrowed. The
Hydrocracker Loan was collateralized by a second lien on the refinery. As
discussed above, the Hydrocracker Loan was repaid and terminated on May 29,
1998.
Vacuum Unit Loan
In 1994, the NBA and the AIDEA provided a $15 million loan to the Company
towards the cost of the Company's refinery vacuum unit ("Vacuum Unit Loan"). The
Vacuum Unit Loan which was to mature on January 1, 2002, required equal
quarterly payments of approximately $536,000 and incurred interest at the
unsecured 90-day commercial paper rate, adjusted quarterly, plus 2.6% per annum
(8.11% at December 31, 1997) for two-thirds of the amount borrowed and at the
National Bank of Alaska floating prime rate plus one-fourth of 1% per annum
(8.75% at December 31, 1997) for the remainder. The Vacuum Unit Loan was
collateralized by a first lien on the Company's refinery. As discussed above,
the Vacuum Unit Loan was repaid and terminated on May 29, 1998.
Department of Energy
A Consent Order entered into by the Company with the Department of Energy
("DOE") in 1989 settled all issues relating to the Company's compliance with
federal petroleum price and allocation regulations from 1973 through decontrol
in 1981. At March 31, 1998, the Company's remaining obligation is to pay the DOE
$7.9 million, exclusive of interest at 6%, over the next four years.
Repurchase of Debentures and Notes
In November 1996, the Company fully redeemed its two public debt issues,
totaling approximately $74 million, at a price equal to 100% of the principal
amount, plus accrued interest to the redemption date. The redemption of debt was
comprised of $44.1 million of outstanding 13% Exchange Notes and $30 million of
outstanding 12 3/4% Subordinated Debentures ("Subordinated Debentures"). The
redemption was accounted for as an early extinguishment of debt in the 1996
third quarter, resulting in a pretax charge of $3.2 million ($2.3 million
aftertax) which represented a write-off of unamortized bond discount and issue
costs. The extraordinary loss on debt extinguishments of $2.9 million in 1995
related to the redemption of $34.6 million principal amount of Subordinated
Debentures in December 1995.
F-20
<PAGE> 159
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
NOTE J -- BENEFIT PLANS
Retirement Plan
For all eligible employees, the Company provides a qualified
noncontributory retirement plan. Plan benefits are based on years of service and
compensation. The Company's funding policy is to make contributions at a minimum
in accordance with the requirements of applicable laws and regulations, but no
more than the amount deductible for income tax purposes. The components of net
pension expense for the Company's retirement plan are presented below (in
thousands):
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
-----------------------------
1995 1996 1997
------- ------- -------
<S> <C> <C> <C>
Service Costs......................................... $ 1,147 $ 1,306 $ 1,502
Interest Cost......................................... 3,549 3,536 3,696
Actual Return on Plan Assets.......................... (8,299) (6,212) (8,817)
Net Amortization and Deferral......................... 4,288 1,687 4,105
------- ------- -------
Net Pension Expense................................. $ 685 $ 317 $ 486
======= ======= =======
</TABLE>
For the three months ended March 31, 1997 and 1998, net pension expense for
the Company's retirement plan totaled $89,000 and $47,000, respectively.
The funded status of the Company's retirement plan and amounts included in
the Company's Consolidated Balance Sheets are set forth in the following table
(in thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
------------------
1996 1997
------- -------
<S> <C> <C>
Actuarial Present Value of Benefit Obligation:
Vested benefit obligation................................. $40,539 $41,601
======= =======
Accumulated benefit obligation............................ $43,404 $44,877
======= =======
Plan Assets at Fair Value................................... $46,356 $50,982
Projected Benefit Obligation................................ 50,163 52,685
------- -------
Plan Assets Less Than Projected Benefit Obligation.......... 3,807 1,703
Unrecognized Net Loss....................................... (5,903) (2,003)
Unrecognized Prior Service Costs............................ 341 267
Unrecognized Net Transition Asset........................... 3,176 1,940
------- -------
Accrued Pension Liability................................. $ 1,421 $ 1,907
======= =======
</TABLE>
Retirement plan assets are primarily comprised of common stock and bond
funds. Actuarial assumptions used to measure the projected benefit obligations
included a discount rate of 7 1/2% and a compensation increase rate of 5% for
December 31, 1995, 1996 and 1997. The expected long-term rate of return on
assets was 8 1/2% for 1995, 1996 and 1997.
F-21
<PAGE> 160
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Executive Security Plan
The Company's executive security plan ("ESP") provides executive officers
and other key personnel with supplemental death or retirement benefits in
addition to those benefits available under the Company's group life insurance
and retirement plans. These supplemental retirement benefits are provided by a
nonqualified, noncontributory plan and are based on years of service and
compensation. Contributions are made by the Company based upon the estimated
requirements of the plan. The components of net pension expense for the ESP are
presented below (in thousands):
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
-------------------------
1995 1996 1997
------ ----- ------
<S> <C> <C> <C>
Service Costs............................................. $ 364 $ 354 $ 521
Interest Cost............................................. 205 204 363
Actual Return on Plan Assets.............................. (325) (439) (596)
Net Amortization and Deferral............................. 471 751 1,196
------ ----- ------
Net Pension Expense..................................... $ 715 $ 870 $1,484
====== ===== ======
</TABLE>
For the three months ended March 31, 1997 and 1998, net pension expense for
the ESP totaled $419,000 and $497,000, respectively.
During the years ended December 31, 1995, 1996 and 1997, the Company
incurred additional ESP expense of $1.5 million, $0.9 million and $1.2 million,
respectively, for settlements, curtailments and other benefits resulting from
employee terminations.
The funded status of the ESP and amounts included in the Company's
Consolidated Balance Sheets are set forth in the following table (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
----------------
1996 1997
------ ------
<S> <C> <C>
Actuarial Present Value of Benefit Obligation:
Vested benefit obligation................................. $3,300 $4,885
====== ======
Accumulated benefit obligation............................ $4,434 $5,585
====== ======
Plan Assets at Fair Value................................... $7,139 $7,732
Projected Benefit Obligation................................ 6,467 8,683
------ ------
Plan Assets in Excess of (Less Than) Projected Benefit
Obligation................................................ 672 (951)
Unrecognized Net Loss....................................... 4,532 6,442
Unrecognized Prior Service Costs............................ 537 895
Unrecognized Net Transition Obligation...................... 417 314
------ ------
Prepaid Pension Asset..................................... $6,158 $6,700
====== ======
</TABLE>
Assets of the ESP consist of a group annuity contract. Actuarial
assumptions used to measure the projected benefit obligation at December 31,
1995, 1996 and 1997 included a discount rate of 7 1/2% and a compensation
increase rate of 5%. The expected long-term rate of return on assets was 8% for
1995 and 1996 and 7% for 1997.
Retiree Health Care and Life Insurance Benefits
The Company provides health care and life insurance benefits to retirees
who were participating in the Company's group insurance program at retirement.
Health care is also provided to qualified dependents of participating retirees.
These benefits are provided through unfunded, defined benefit plans. The health
care
F-22
<PAGE> 161
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
plans are contributory, with retiree contributions adjusted periodically, and
contain other cost-sharing features such as deductibles and coinsurance. The
life insurance plan is noncontributory. The Company funds its share of the cost
of postretirement health care and life insurance benefits on a pay-as-you-go
basis. The components of net periodic postretirement benefits expense, other
than pensions, included the following (in thousands):
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
--------------------------
1995 1996 1997
------ ------ ------
<S> <C> <C> <C>
Health Care:
Service costs.......................................... $ 447 $ 558 $ 676
Interest costs......................................... 1,399 1,294 1,304
------ ------ ------
Net Periodic Postretirement Expense................. $1,846 $1,852 $1,980
====== ====== ======
Life Insurance:
Service costs.......................................... $ 174 $ 158 $ 190
Interest costs......................................... 584 548 580
------ ------ ------
Net Periodic Postretirement Expense................. $ 758 $ 706 $ 770
====== ====== ======
</TABLE>
For the three months ended March 31, 1997 and 1998, retiree health care
benefits totaled $472,000 and $508,000, respectively, and retiree life insurance
benefits totaled $200,000 and $199,000, respectively.
The following tables show the status of the plans reconciled with the
amounts in the Company's Consolidated Balance Sheets (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
------------------
1996 1997
------- -------
<S> <C> <C>
Health Care:
Accumulated Postretirement Benefit Obligation --
Retirees.................................................. $12,549 $12,591
Active participants eligible to retire.................... 1,203 1,638
Other active participants................................. 4,181 4,584
------- -------
17,933 18,813
Unrecognized Net Gain....................................... 2,621 3,211
------- -------
Accrued Postretirement Benefit Liability............... $20,554 $22,024
======= =======
Life Insurance:
Accumulated Postretirement Benefit Obligation --
Retirees.................................................. $ 6,274 $ 6,393
Active participants eligible to retire.................... 484 608
Other active participants................................. 1,205 1,299
------- -------
7,963 8,300
Unrecognized Net Loss....................................... (115) (380)
------- -------
Accrued Postretirement Benefit Liability............... $ 7,848 $ 7,920
======= =======
</TABLE>
The weighted average annual rate of increase in the per capita cost of
covered health care benefits is assumed to be 8% for 1998, decreasing gradually
to 6% by the year 2005 and remaining at that level thereafter. This health care
cost trend rate assumption has a significant effect on the amount of the
obligation and periodic cost reported. For example, an increase in the assumed
health care cost trend rates by one percentage point in each year would increase
the accumulated postretirement obligation at December 31, 1997 by $3.8 million
and the aggregate of service cost and interest cost components of net periodic
postretirement benefits for the year then ended by $0.5 million. Actuarial
assumptions used to measure the accumulated
F-23
<PAGE> 162
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
postretirement benefit obligation at December 31, 1995, 1996 and 1997 included a
discount rate of 7 1/2% and a compensation rate increase of 5%.
Thrift Plan
The Company sponsors an employee thrift plan which provides for
contributions by eligible employees into designated investment funds with a
matching contribution by the Company. Employees may contribute up to 10% of
their compensation, subject to certain limitations, and may elect tax deferred
treatment in accordance with the provisions of Section 401(k) of the Internal
Revenue Code. Effective October 1, 1996, the thrift plan was amended to change
the Company's matching contribution from 50% (of up to 6% of the employee's
eligible contribution) to 100% (of up to 4% of the employee's eligible
contributions), with at least 50% of the Company's match invested in Common
Stock of the Company. The Company's contributions amounted to $0.4 million, $0.8
million and $1.2 million during the year ended December 31, 1995, 1996 and 1997,
respectively. For the three months ended March 31, 1997 and 1998, the Company's
contributions amounted to $0.3 million and $0.4 million, respectively.
Non-Employee Director Retirement Plan and Phantom Stock Plan
The Company had previously established an unfunded Non-Employee Director
Retirement Plan ("Director Retirement Plan"), which provided that any eligible
non-employee director who had served on the Company's Board of Directors for at
least three full years would be entitled to a retirement payment in cash
beginning the later of the director's sixty-fifth birthday or such later date
that the individual's service as a director ended. However, to more closely
align director compensation with shareholders' interests, in March 1997, the
Board of Directors amended the Director Retirement Plan to freeze the plan and
convert all of the accrued benefits of the current directors under the plan to a
lump-sum present value which was transferred to and became the initial account
balance of the directors in the Tesoro Petroleum Corporation Board of Directors
Deferred Phantom Stock Plan ("Phantom Stock Plan"). After the amendment and
transfer, only those retired directors or beneficiaries who had begun receiving
benefits remained participants in the Director Retirement Plan. At December 31,
1996 and 1997, the projected benefit obligation and present value of the vested
and accumulated benefit obligations, discounted at 7 1/2%, of the Director
Retirement Plan were estimated to be $0.8 million and $0.4 million,
respectively. The Company's Consolidated Balance Sheets at December 31, 1996 and
1997 and March 31, 1998, included $0.7 million, $0.4 million and $0.4 million,
respectively, in other liabilities related to the Director Retirement Plan.
Upon establishment of the Phantom Stock Plan, the lump-sum accrued benefit
of each of the current non-employee directors was transferred from the Director
Retirement Plan into an account ("Account") in the Phantom Stock Plan. Under the
Phantom Stock Plan, a yearly credit of $7,250 (prorated to $6,042 for 1997) is
made to the Account of each director in units, based upon the closing market
price of the Company's Common Stock on the date of credit. In addition, a
director may elect to have the value of his cash retainer fee deposited
quarterly into the Account in units. The value of each Account balance, which is
a function of the amount, if any, by which the market value of the Company's
Common Stock changes, is payable in cash at retirement, death, disability or
termination, if vested. In the year ended December 31, 1997 and the three months
ended March 31, 1998, the Company incurred expenses of approximately $127,000
and $84,000, respectively, related to the Phantom Stock Plan due to the increase
in the market price of the Company's Common Stock.
NOTE K -- STOCKHOLDERS' EQUITY
For information related to a universal shelf registration and related
offerings of Common Stock and PIES, see Note I.
F-24
<PAGE> 163
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Stock Repurchase Program
On May 7, 1997, the Company's Board of Directors authorized the repurchase
of up to 3 million shares (approximately 11% of outstanding shares) of Tesoro
Common Stock in a buyback program that was scheduled to conclude at the end of
1998. Under the program, subject to certain conditions, the Company repurchased
from time to time Tesoro Common Stock in the open market and through privately
negotiated transactions. Purchases depended on price, market conditions and
other factors and were made primarily from cash flows. The repurchased Common
Stock is accounted for as treasury stock and may be used for employee benefit
plan requirements and other corporate purposes. During the year ended December
31, 1997, the Company used cash flows of $3.7 million to repurchase 236,800
shares of Common Stock, of which 20,347 shares have been reissued for an
employee benefit plan. In connection with filing the Registration Statement
discussed in Note I, the Company's Board of Directors approved terminating the
repurchase of Tesoro's Common Stock since it is inconsistent with the shelf
registration and the Company's growth strategy (see Note I).
Stock Plans and Incentive Compensation Strategy
The Company has two employee incentive stock plans, the Amended and
Restated Executive Long-Term Incentive Plan ("1993 Plan") and Amended Incentive
Stock Plan of 1982 ("1982 Plan"), and the 1995 Non-Employee Director Stock
Option Plan ("1995 Plan") (collectively, the "Plans"). Shares of unissued Common
Stock reserved for the Plans were 2,717,611 at December 31, 1997.
The 1993 Plan provides for the grant of up to 2,650,000 shares of the
Company's Common Stock in a variety of forms, including restricted stock,
incentive stock options, nonqualified stock options, stock appreciation rights
and performance share and performance unit awards. Stock options may be granted
at exercise prices not less than the fair market value on the date the options
are granted. The options granted generally become exercisable after one year in
20%, 25% or 33% increments per year and expire ten years from date of grant. The
1993 Plan will expire, unless earlier terminated, as to the issuance of awards
in the year 2003. At December 31, 1997, the Company had 66,420 shares available
for future grants under the 1993 Plan. At the 1998 Annual Meeting of
Stockholders held on July 29, 1998, the Company's stockholders approved an
amendment to the 1993 Plan which increases the total number of shares which can
be granted from 2,650,000 to 4,250,000.
In the year ended December 31, 1997, the Compensation Committee of the
Board of Directors granted 175,000 phantom stock options to an executive officer
of the Company. These phantom stock options, which were granted at 100% of the
fair market value of the Company's Common Stock on the grant date, vest in 15%
increments in each of the first three years and the remaining 55% increment
vests in the fourth year. Upon exercise, the executive officer would be entitled
to receive in cash the difference between the fair market value of the Common
Stock on the date of the phantom stock option grant and the fair market value of
Common Stock on the date of exercise. At the discretion of the Compensation
Committee, these phantom stock options may be converted to traditional stock
options upon sufficient shares becoming available under the 1993 Plan.
The 1982 Plan expired in 1994 as to issuance of stock appreciation rights,
stock options and stock awards; however, grants made before the expiration date
that have not been fully exercised remain outstanding pursuant to their terms.
The 1995 Plan provides for the grant of up to an aggregate of 150,000
nonqualified stock options to eligible non-employee directors of the Company.
The option price per share is equal to the fair market value per share of the
Company's Common Stock on the date of grant. The term of each option is ten
years, and an option first becomes exercisable six months after the date of
grant. Under the 1995 Plan, each person serving as a non-employee director on
February 23, 1995 or elected thereafter, initially received an option to
purchase 5,000 shares of Common Stock. Thereafter, each non-employee director,
while the 1995 Plan is in effect and
F-25
<PAGE> 164
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
shares are available to grant, will be granted an option to purchase 1,000
shares of Common Stock on the next day after each annual meeting of the
Company's stockholders but not later than June 1, if no annual meeting is held.
At December 31, 1997, the Company had 68,000 options outstanding and 77,000
shares available for future grants under the 1995 Plan.
In June 1996, the Company's Board of Directors unanimously approved a
special incentive compensation strategy in order to encourage a longer-term
focus for all employees to perform at an outstanding level. The strategy
provides eligible employees with incentives to achieve a significant increase in
the market price of the Company's Common Stock. Under the strategy, awards would
be earned only if the market price of the Company's Common Stock reaches an
average price per share of $20 or higher over any 20 consecutive trading days
after June 30, 1997 and before December 31, 1998 (the "Performance Target"). In
connection with this strategy, non-executive employees will be able to earn cash
bonuses equal to 25% of their individual payroll amounts for the previous twelve
complete months and certain executives have been granted, from the 1993 Plan, a
total of 340,000 stock options at an exercise price of $11.375 per share, the
fair market value (as defined in the 1993 Plan) of a share of the Company's
Common Stock on the date of grant, and 350,000 shares of restricted Common
Stock, all of which vest only upon achieving the Performance Target.
On May 12, 1998, the Performance Target was achieved which will result in a
pretax charge of approximately $20 million ($10 million in cash and $10 million
related to the vesting of restricted stock awards and stock options) in the
second quarter of 1998. On an aftertax basis, the charge will be approximately
$13 million, representing 5% of the total aggregate increase in shareholder
value since approval of the special incentive strategy in 1996.
A summary of stock option activity in the Plans is set forth below:
<TABLE>
<CAPTION>
NUMBER OF
OPTIONS WEIGHTED-AVERAGE
OUTSTANDING EXERCISE PRICE
----------- ----------------
<S> <C> <C>
Outstanding December 31, 1994............................ 1,496,293 $ 6.37
Granted................................................ 450,000 8.34
Exercised.............................................. (507,467) 4.85
Forfeited and expired.................................. (266,745) 9.10
---------
Outstanding December 31, 1995............................ 1,172,081 7.16
Granted................................................ 1,095,500 13.45
Exercised.............................................. (315,664) 5.67
Forfeited and expired.................................. (95,171) 8.50
---------
Outstanding December 31, 1996............................ 1,856,746 11.05
Granted................................................ 431,000 16.73
Exercised.............................................. (43,800) 8.45
Forfeited and expired.................................. (36,013) 8.40
---------
Outstanding December 31, 1997............................ 2,207,933 12.26
=========
</TABLE>
At December 31, 1995, 1996 and 1997, exercisable stock options totaled 0.4
million, 0.4 million and 0.7 million, respectively.
F-26
<PAGE> 165
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The following table summarizes information about stock options outstanding
under the Plans at December 31, 1997:
<TABLE>
<CAPTION>
OPTIONS OUTSTANDING
------------------------------------------------- OPTIONS EXERCISABLE
WEIGHTED-AVERAGE ------------------------------
RANGE OF NUMBER REMAINING WEIGHTED-AVERAGE NUMBER WEIGHTED-AVERAGE
EXERCISE PRICES OUTSTANDING CONTRACTUAL LIFE EXERCISE PRICE EXERCISABLE EXERCISE PRICE
--------------- ----------- ---------------- ---------------- ----------- ----------------
<S> <C> <C> <C> <C> <C>
$ 3.92 to $ 7.19 179,740 5.2 years $ 4.52 159,272 $ 4.42
$ 7.20 to $10.45 551,100 7.5 years 8.65 279,300 8.84
$10.46 to $13.72 398,593 8.4 years 11.41 31,593 11.68
$13.73 to $16.98 1,078,500 9.2 years 15.72 210,173 14.94
--------- ---------
$ 3.92 to $16.98 2,207,933 8.3 years 12.26 680,338 9.82
========= =========
</TABLE>
The Company applies APB No. 25 and related interpretations in accounting
for its stock plans. Accordingly, no compensation expense has been recognized
for stock option transactions or the incentive compensation strategy discussed
above. Had compensation cost for the Plans been determined based on the fair
value at the grant dates for awards (granted after January 1, 1995) in
accordance with SFAS No. 123, "Accounting for Stock-Based Compensation," the
Company's pro forma net earnings in the years ended December 31, 1995, 1996 and
1997 would have been approximately $53.8 million ($2.19 per basic share, $2.15
per diluted share), $72.6 million ($2.79 per basic share, $2.74 per diluted
share), and $28.5 million ($1.08 per basic share, $1.06 per diluted share),
respectively. The fair value of each option grant was estimated on the date of
grant using the Black-Scholes option-pricing model with the following weighted-
average assumptions: expected volatility of 45%, 30% and 32%; risk free interest
rates of 6.1%, 6.6% and 6.7%; expected lives of seven years; and no dividend
yields for the years 1995, 1996 and 1997, respectively. The estimated fair value
per share of options granted during the years 1995, 1996 and 1997 were $3.65,
$4.26 and $5.96, respectively, and the fair value per share of restricted stock
awards in the year 1996 was $0.95 per share.
NOTE L -- COMMITMENTS AND CONTINGENCIES
Operating Leases
The Company has various noncancellable operating leases related to
buildings, equipment, property and other facilities. These long-term leases have
remaining primary terms generally up to ten years, with terms of certain
rights-of-way extending up to 34 years, and generally contain multiple renewal
options. Future minimum annual lease payments as of December 31, 1997, for
operating leases having initial or remaining noncancelable lease terms in excess
of one year, excluding marine charters, were as follows (in thousands):
<TABLE>
<S> <C>
1998........................................................ $ 6,135
1999........................................................ 3,378
2000........................................................ 2,907
2001........................................................ 2,514
2002........................................................ 2,272
Remainder................................................... 13,962
-------
Total Minimum Lease Payments.............................. $31,168
=======
</TABLE>
In addition to the long-term lease commitments above, the Company has
leases for two vessels that are primarily used to transport crude oil and
refined products to and from the Company's refinery. At December 31, 1997,
future minimum annual lease payments remaining for these two vessels, which
include operating costs, are approximately $28 million for each of the years
1998 and 1999 and $16 million for the year 2000. Operating costs related to
these vessels, which may vary from year to year, comprised approximately
F-27
<PAGE> 166
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
30% of the total minimum payments during 1997. The Company also enters into
various month-to-month and other short-term rentals, including a charter of a
vessel primarily used to transport refined products from the Company's refinery
to the Far East.
Total rental expense for short-term and long-term leases, excluding marine
charters, amounted to approximately $10 million, $12 million, $11 million, $4
million and $4 million for the years ended December 31, 1995, 1996 and 1997 and
three months ended March 31, 1997 and 1998, respectively. In addition, expenses
related to charters of marine vessels were approximately $26 million, $30
million, $34 million, $8 million and $8 million for the years ended December 31,
1995, 1996 and 1997 and three months ended March 31, 1997 and 1998,
respectively.
Environmental
The Company is subject to extensive federal, state and local environmental
laws and regulations. These laws, which change frequently, regulate the
discharge of materials into the environment and may require the Company to
remove or mitigate the environmental effects of the disposal or release of
petroleum or chemical substances at various sites or install additional controls
or other modifications or changes in use for certain emission sources. The
Company is currently involved with a waste disposal site near Abbeville,
Louisiana, at which it has been named a potentially responsible party under the
Federal Superfund law. Although this law might impose joint and several
liability upon each party at the site, the extent of the Company's allocated
financial contributions to the cleanup of the site is expected to be limited
based upon the number of companies, volumes of waste involved, and an estimated
total cost of approximately $500,000 among all of the parties to close the site.
The Company is currently involved in settlement discussions with the
Environmental Protection Agency ("EPA") and other potentially responsible
parties at the Abbeville, Louisiana site. The Company expects, based on these
discussions, that its liability will not exceed $25,000. The Company is also
involved in remedial responses and has incurred cleanup expenditures associated
with environmental matters at a number of sites, including certain of its own
properties.
At December 31, 1997 and March 31, 1998, the Company's accruals for
environmental expenses amounted to $8.5 million and $8.7 million, respectively,
which included a noncurrent liability of $2.7 million and $2.5 million,
respectively, for remediation of the Kenai Pipe Line Company's ("KPL")
properties that has been funded by the former owners of KPL through a restricted
escrow deposit. Based on currently available information, including the
participation of other parties or former owners in remediation actions, the
Company believes these accruals are adequate.
To comply with environmental laws and regulations, the Company anticipates
that it will make capital improvements of approximately $7 million in the year
1998 and $2 million in the year 1999. In addition, capital expenditures for
alternate secondary containment systems for existing storage tank facilities are
estimated to be $2 million in the year 1998 and $2 million in the year 1999 with
a remaining $5 million to be spent by 2002.
Conditions that require additional expenditures may exist for various
Company sites, including, but not limited to, the Company's refinery, retail
gasoline stations (current and closed locations) and petroleum product
terminals, and for compliance with the Clean Air Act. The amount of such future
expenditures cannot currently be determined by the Company.
Crude Oil Purchase Contracts and Other
The Company has a contract with the State of Alaska for the purchase of
royalty crude oil covering the period January 1, 1996 through December 31, 1998.
The contract provides for the purchase of 30% of the State's ANS royalty crude
oil produced from the Prudhoe Bay Unit at prices based on royalty values
computed by the State. During the year ended December 31, 1997, the Company
purchased approximately
F-28
<PAGE> 167
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
35,700 barrels per day of ANS crude oil under this contract. The contract
contains provisions that, under certain conditions, allow the Company to
temporarily or permanently reduce its purchase obligations. Under this contract,
the Company is required to utilize in its refinery operations volumes equal to
at least 80% of the ANS crude oil purchased from the State. The Company is
presently in discussions with the State in regard to extending this contract for
an additional year.
The Company also purchases approximately 6,000 barrels per day of ANS crude
oil from a producer under a contract with a term of one year beginning January
1, 1998.
During October 1997, the Company began purchasing all of the approximately
34,000 barrels per day of Cook Inlet crude oil production from various producers
under contracts extending through December 1998. A contract to purchase 4,500
barrels per day, of the 34,000 barrels per day, has been extended through March
31, 2001.
The second quarter of 1998 will reflect receipt of approximately $21
million pretax ($14 million aftertax) from an operator in the Bob West Field,
representing funds that are no longer needed as a contingency reserve for
litigation.
NOTE M -- QUARTERLY FINANCIAL DATA (UNAUDITED)
<TABLE>
<CAPTION>
QUARTERS
--------------------------------------- TOTAL
FIRST SECOND THIRD FOURTH YEAR
------ ------ ------ ------ --------
(IN MILLIONS EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C>
1996
Revenues:
Gross operating revenues............ $238.6 $233.8 $262.8 $240.2 $ 975.4
Income from settlement of natural
gas contract...................... -- -- -- 60.0 60.0
Other income........................ 5.0 0.1 (0.7) -- 4.4
------ ------ ------ ------ --------
Total Revenues................. $243.6 $233.9 $262.1 $300.2 $1,039.8
====== ====== ====== ====== ========
Operating Profit....................... $ 20.7 $ 27.6 $ 25.2 $ 71.3 $ 144.8
====== ====== ====== ====== ========
Earnings Before Extraordinary Item..... $ 6.0 $ 12.0 $ 16.2 $ 42.6 $ 76.8
Extraordinary Loss on Debt
Extinguishments, Net................ -- -- (2.3) -- (2.3)
------ ------ ------ ------ --------
Net Earnings................... $ 6.0 $ 12.0 $ 13.9 $ 42.6 $ 74.5
====== ====== ====== ====== ========
Net Earnings Per Share -- Basic........ $ 0.24 $ 0.46 $ 0.53 $ 1.62 $ 2.87
Net Earnings Per Share -- Diluted...... $ 0.23 $ 0.45 $ 0.52 $ 1.59 $ 2.81
Market Price Per Common Share:
High................................ $ 9 1/8 $ 11 5/8 $ 13 1/2 $ 15 1/2
Low................................. $ 8 $ 8 1/4 $ 10 1/2 $ 12 7/8
1997
Revenues:
Gross operating revenues............ $233.3 $210.7 $251.0 $242.9 $ 937.9
Other income........................ 1.6 2.6 0.4 0.9 5.5
------ ------ ------ ------ --------
Total Revenues................. $234.9 $213.3 $251.4 $243.8 $ 943.4
====== ====== ====== ====== ========
Operating Profit....................... $ 15.0 $ 19.9 $ 19.4 $ 18.4 $ 72.7
====== ====== ====== ====== ========
Net Earnings........................... $ 6.1 $ 9.7 $ 8.0 $ 6.9 $ 30.7
====== ====== ====== ====== ========
Net Earnings Per Share -- Basic........ $ 0.23 $ 0.36 $ 0.30 $ 0.26 $ 1.16
Net Earnings Per Share -- Diluted...... $ 0.23 $ 0.36 $ 0.30 $ 0.26 $ 1.14
</TABLE>
F-29
<PAGE> 168
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
QUARTERS
---------------------------------------
FIRST SECOND THIRD FOURTH
------ ------ ------ ------
(IN MILLIONS EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C>
Market Price per Common Share:
High........................................ $ 14 1/2 $ 15 $ 18 3/16 $ 18 3/16
Low......................................... $ 10 3/8 $ 10 1/4 $ 14 3/4 $ 15
</TABLE>
During the three months ended March 31, 1998, the Company's quarterly
financial data was as follows: gross operating revenues of $195.2 million; other
income of $0.8 million; operating profit of $17.9 million; net earnings of $6.1
million; earnings per share, basic and diluted, of $0.23 per share; and high and
low Common Stock market prices per share of $17 7/8 and $14 13/16, respectively.
The 1996 first quarter included pretax other income of $5 million related
to retroactive severance tax refunds. The 1996 third quarter included pretax
income of $8 million for interest and reimbursement of costs from Tennessee Gas
(see Note D) and an aftertax extraordinary loss of $2.3 million for the early
extinguishment of debt (see Note I). The contract with Tennessee Gas was
terminated during the 1996 fourth quarter resulting in pretax income of $60
million (see Note D). Operating profit included approximately $8 million pretax
in each of the first, second and third quarters of 1996 from the excess of
natural gas contract prices over spot market prices.
Pretax other income related to severance tax refunds of $1.6 million and
$0.2 million were recorded in the 1997 first and second quarters, respectively.
Pretax other income of $2.2 million related to the collection of a Bolivian
receivable for prior years production was recorded in the 1997 second quarter.
NOTE N -- OIL AND GAS PRODUCING ACTIVITIES
The information presented below represents the oil and gas producing
activities of the Company's Exploration and Production segment, excluding
amounts related to its U.S. natural gas transportation operations. Other
information pertinent to the Exploration and Production segment is contained in
Notes B, C and D.
Capitalized Costs Relating to Oil and Gas Producing Activities
<TABLE>
<CAPTION>
DECEMBER 31,
--------------------------------
1995 1996 1997
-------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C>
Capitalized Costs:
Proved properties................................ $119,836 $179,433 $251,604
Unproved properties not being amortized.......... 5,118 12,344 31,918
-------- -------- --------
124,954 191,777 283,522
Accumulated depreciation, depletion and
amortization.................................. 51,549 78,222 112,562
-------- -------- --------
Net Capitalized Costs......................... $ 73,405 $113,555 $170,960
======== ======== ========
</TABLE>
The Company's investment in oil and gas properties included $31.9 million
in unevaluated properties, primarily undeveloped leasehold costs and seismic
costs, which have been excluded from the amortization base at December 31, 1997.
Of this amount, $5.6 million and $26.3 million of such costs were incurred in
the years ended December 31, 1996 and 1997, respectively. The Company
anticipates that the majority of these costs will be included in the
amortization base during the next two years.
F-30
<PAGE> 169
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Costs Incurred in Oil and Gas Property Acquisition, Exploration and
Development Activities
<TABLE>
<CAPTION>
U.S. BOLIVIA TOTAL
------- ------- -------
(IN THOUSANDS)
<S> <C> <C> <C>
YEAR ENDED DECEMBER 31, 1995
Property acquisition, unproved...................... $ 1,432 $ -- $ 1,432
Exploration......................................... 10,011 2,994 13,005
Development......................................... 38,003 792 38,795
------- ------- -------
$49,446 $ 3,786 $53,232
======= ======= =======
YEAR ENDED DECEMBER 31, 1996
Property acquisitions --
Proved........................................... $20,454 $ -- $20,454
Unproved......................................... 5,216 -- 5,216
Exploration......................................... 11,830 6,704 18,534
Development......................................... 22,228 149 22,377
------- ------- -------
$59,728 $ 6,853 $66,581
======= ======= =======
YEAR ENDED DECEMBER 31, 1997
Property acquisitions --
Proved........................................... $14,723 $11,892 $26,615
Unproved......................................... 7,127 3,370 10,497
Exploration......................................... 24,584 10,972 35,556
Development......................................... 17,798 1,279 19,077
------- ------- -------
$64,232 $27,513 $91,745
======= ======= =======
</TABLE>
Results of Operations from Oil and Gas Producing Activities
The following table sets forth the results of operations for oil and gas
producing activities, in the aggregate by geographic area, with income tax
expense computed using the statutory tax rate for the period adjusted for
permanent differences, tax credits and allowances.
<TABLE>
<CAPTION>
U.S. BOLIVIA TOTAL
---- -------- -----
(IN THOUSANDS EXCEPT AS INDICATED)
<S> <C> <C> <C>
YEAR ENDED DECEMBER 31, 1995
Gross revenues -- sales to unaffiliates(a)........ $107,276 $11,707 $118,983
Production costs.................................. 12,005 600 12,605
Administrative support and other.................. 2,842 3,289 6,131
Gain on sales of assets(e)........................ 33,532 -- 33,532
Depreciation, depletion and amortization.......... 29,004 250 29,254
-------- ------- --------
Pretax results of operations...................... 96,957 7,568 104,525
Income tax expense................................ 33,935 4,718 38,653
-------- ------- --------
Results of operations from producing
activities(c).................................. $ 63,022 $ 2,850 $ 65,872
======== ======= ========
Depletion per Mcfe................................ $ 0.69 $ 0.03
======== =======
</TABLE>
F-31
<PAGE> 170
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
U.S. BOLIVIA TOTAL
---- -------- -----
(IN THOUSANDS EXCEPT AS INDICATED)
<S> <C> <C> <C>
YEAR ENDED DECEMBER 31, 1996
Gross revenues -- sales to unaffiliates(a)........ $ 88,358 $13,701 $102,059
Production costs.................................. 5,326 837 6,163
Administrative support and other.................. 3,649 2,830 6,479
Depreciation, depletion and amortization.......... 25,235 1,279 26,514
Income from settlement of a natural gas
contract(d).................................... 60,000 -- 60,000
Income from severance tax refunds................. 5,000 -- 5,000
-------- ------- --------
Pretax results of operations...................... 119,148 8,755 127,903
Income tax expense................................ 41,702 5,439 47,141
-------- ------- --------
Results of operations from producing
activities(c).................................. $ 77,446 $ 3,316 $ 80,762
======== ======= ========
Depletion per Mcfe................................ $ 0.79 $ 0.15
======== =======
YEAR ENDED DECEMBER 31, 1997
Gross revenues -- sales to unaffiliates(a)........ $ 68,843 $11,189 $ 80,032
Production costs.................................. 7,424 932 8,356
Administrative support and other.................. 2,217 2,321 4,538
Depreciation, depletion and amortization.......... 29,350 1,538 30,888
Other income(b)................................... 3,238 2,184 5,422
-------- ------- --------
Pretax results of operations...................... 33,090 8,582 41,672
Income tax expense................................ 11,582 4,915 16,497
-------- ------- --------
Results of operations from producing
activities(c).................................. $ 21,508 $ 3,667 $ 25,175
======== ======= ========
Depletion per net equivalent thousand cubic feet
("Mcfe")....................................... $ 0.93 $ 0.19
======== =======
</TABLE>
- ---------------
(a) Revenues included the effects of natural gas commodity price agreements
which amounted to a gain of $0.3 million ($0.01 per thousand cubic feet
("Mcf")) in the year ended December 31, 1995 and losses of $3.1 million
($0.11 per Mcf) and $1.6 million ($0.05 per Mcf) in the years ended
December 31, 1996 and 1997, respectively. The Company had entered into
these agreements to reduce risks caused by fluctuations in the prices of
natural gas in the spot market. During the years ended December 31, 1995,
1996 and 1997, the Company used such agreements to set the price of 38%,
30% and 9%, respectively, of the natural gas that it sold in the spot
market. The Company has no remaining natural gas price agreements
outstanding at December 31, 1997 or March 31, 1998.
(b) Primarily represents income from retroactive severance tax refunds in the
U.S. operations and income related to a collection of a receivable in
Bolivian operations.
(c) Excludes corporate general and administrative expenses and financing costs.
(d) See Note D.
(e) Represents gain on sale of certain interests in the Bob West Field (see
Note C).
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved
Reserves (Unaudited)
The following table sets forth the computation of the standardized measure
of discounted future net cash flows relating to proved reserves and the changes
in such cash flows in accordance with SFAS No. 69. The standardized measure is
the estimated excess future cash inflows from proved reserves less estimated
future production and development costs, estimated future income taxes and a
discount factor. Future cash inflows represent expected revenues from production
of year-end quantities of proved reserves based on year-end
F-32
<PAGE> 171
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
prices and any fixed and determinable future escalation provided by contractual
arrangements in existence at year-end. Escalation based on inflation, federal
regulatory changes and supply and demand are not considered. Estimated future
production costs related to year-end reserves are based on year-end costs. Such
costs include, but are not limited to, production taxes and direct operating
costs. Inflation and other anticipatory costs are not considered until the
actual cost change takes effect. Estimated future income tax expenses are
computed using the appropriate year-end statutory tax rates. Consideration is
given for the effects of permanent differences, tax credits and allowances. A
discount rate of 10% is applied to the annual future net cash flows.
The methodology and assumptions used in calculating the standardized
measure are those required by SFAS No. 69. The standardized measure is not
intended to be representative of the fair market value of the Company's proved
reserves. The calculations of revenues and costs do not necessarily represent
the amounts to be received or expended by the Company.
<TABLE>
<CAPTION>
U.S. BOLIVIA TOTAL
-------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C>
DECEMBER 31, 1995
Future cash inflows.............................. $265,379 $120,510 $385,889
Future production costs.......................... 53,095 32,005 85,100
Future development costs......................... 8,625 7,548 16,173
-------- -------- --------
Future net cash flows before income tax
expense....................................... 203,659 80,957 284,616
10% annual discount factor....................... 34,920 32,231 67,151
-------- -------- --------
Discounted future net cash flows before income
taxes......................................... 168,739 48,726 217,465
Discounted future income tax expense(a).......... 45,939 25,897 71,836
-------- -------- --------
Standardized measure of discounted future net
cash flows.................................... $122,800 $ 22,829 $145,629
======== ======== ========
DECEMBER 31, 1996
Future cash inflows.............................. $376,103 $368,119 $744,222
Future production costs.......................... 66,524 72,766 139,290
Future development costs......................... 13,156 30,632 43,788
-------- -------- --------
Future net cash flows before income tax
expense....................................... 296,423 264,721 561,144
10% annual discount factor....................... 73,687 130,915 204,602
-------- -------- --------
Discounted future net cash flows before income
taxes......................................... 222,736 133,806 356,542
Discounted future income tax expense (a)......... 70,251 80,102 150,353
-------- -------- --------
Standardized measure of discounted future net
cash flows.................................... $152,485 $ 53,704 $206,189
======== ======== ========
DECEMBER 31, 1997
Future cash inflows.............................. $347,904 $490,337 $838,241
Future production costs.......................... 81,011 86,546 167,557
Future development costs......................... 29,362 48,860 78,222
-------- -------- --------
Future net cash flows before income tax
expense....................................... 237,531 354,931 592,462
10% annual discount factor....................... 70,036 148,461 218,497
-------- -------- --------
Discounted future net cash flows before income
taxes......................................... 167,495 206,470 373,965
Discounted future income tax expense(a).......... 32,284 107,318 139,602
-------- -------- --------
Standardized measure of discounted future net
cash flows(b)................................. $135,211 $ 99,152 $234,363
======== ======== ========
</TABLE>
F-33
<PAGE> 172
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
- ---------------
(a) For Bolivia, the discounted future income tax expense includes Bolivian
taxes of $21.6 million, $69.4 million and $105.0 million as of December 31,
1995, 1996 and 1997, respectively, and U.S. income taxes of $4.3 million,
$10.7 million and $2.3 million at December 31, 1995, 1996 and 1997,
respectively.
(b) Gross rates for the Company's Bolivian production were increased from 40
million cubic feet ("MMcf") per day to 120 MMcf per day in the year 2000
due to the anticipated completion of the Bolivia-Brazil pipeline during
early 1999 as discussed in Note B. This increase accounted for
approximately $57 million of the standardized measure of discounted future
net cash flows for Bolivia at December 31, 1997.
Changes in Standardized Measure of Discounted Future Net Cash Flows
(Unaudited)
<TABLE>
<CAPTION>
1995 1996 1997
--------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C>
Sales of oil and gas produced, net of production
costs............................................. $(106,378) $(93,275) $(69,567)
Net changes in prices and production costs.......... (32,931) 39,409 (88,473)
Extensions, discoveries and improved recovery....... 83,045 81,201 42,191
Changes in future development costs................. 19,221 (17,704) (7,495)
Revisions of previous quantity estimates............ 60,800 (7,244) 15,819
Purchases (sales) of minerals in-place.............. (48,698) 55,484 79,024
Changes in timing of Bolivian production............ -- -- 10,271
Extension of Bolivian contract terms................ -- 26,564 --
Other changes in Bolivian Hydrocarbons Law.......... -- 32,894 --
Accretion of discount............................... 14,878 14,563 20,619
Net changes in income taxes......................... 6,917 (71,332) 25,785
--------- -------- --------
Net increase (decrease)............................. (3,146) 60,560 28,174
Beginning of period................................. 148,775 145,629 206,189
--------- -------- --------
End of period....................................... $ 145,629 $206,189 $234,363
========= ======== ========
</TABLE>
F-34
<PAGE> 173
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Reserve Information (Unaudited)
The following estimates of the Company's net proved oil and gas reserves
are based on evaluations prepared by Netherland, Sewell & Associates, Inc.,
except for U.S. net reserves at December 31, 1997 which were prepared by
in-house engineers and audited by Netherland, Sewell & Associates, Inc. Reserves
were estimated in accordance with guidelines established by the Securities and
Exchange Commission and Financial Accounting Standards Board, which require that
reserve estimates be prepared under existing economic and operating conditions
with no provision for price and cost escalations except by contractual
arrangements.
<TABLE>
<CAPTION>
U.S. BOLIVIA TOTAL
------- ------- -------
<S> <C> <C> <C>
NET PROVED GAS RESERVES (millions of cubic feet)(a)
December 31, 1994......................................... 129,099 95,756 224,855
Revisions of previous estimates........................ 46,239 (553) 45,686
Extensions, discoveries and other additions............ 50,201 -- 50,201
Production............................................. (41,789) (6,807) (48,596)
Sales of minerals in-place............................. (77,373) -- (77,373)
------- ------- -------
December 31, 1995......................................... 106,377 88,396 194,773
Extension of Bolivian contract terms(b)................ -- 32,998 32,998
Other changes in Bolivian Hydrocarbons Law(b).......... -- 56,704 56,704
Revisions of previous estimates........................ (4,792) (149) (4,941)
Extensions, discoveries and other additions............ 22,977 59,964 82,941
Production............................................. (32,081) (7,412) (39,493)
Purchases of minerals in-place......................... 24,309 -- 24,309
------- ------- -------
December 31, 1996......................................... 116,790 230,501 347,291
Revisions of previous estimates........................ (3,063) 30,567 27,504
Extensions and discoveries............................. 33,648 -- 33,648
Production............................................. (31,409) (7,131) (38,540)
Purchases of minerals in-place......................... 30,527 81,229 111,756
------- ------- -------
December 31, 1997 (c)..................................... 146,493 335,166 481,659
======= ======= =======
NET PROVED DEVELOPED GAS RESERVES (millions of cubic feet)
December 31, 1994......................................... 110,071 81,558 191,629
December 31, 1995......................................... 95,930 72,500 168,430
December 31, 1996......................................... 107,509 123,154 230,663
December 31, 1997 (c)..................................... 112,385 181,402 293,787
</TABLE>
F-35
<PAGE> 174
TESORO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
<TABLE>
<CAPTION>
U.S. BOLIVIA TOTAL
------- ------- -------
<S> <C> <C> <C>
NET PROVED OIL RESERVES (thousands of barrels)(a)
December 31, 1994......................................... -- 1,793 1,793
Revisions of previous estimates........................ 1 10 11
Extensions, discoveries and other additions............ 8 -- 8
Production............................................. (1) (207) (208)
------- ------- -------
December 31, 1995......................................... 8 1,596 1,604
Extension of Bolivian contract terms(b)................ -- 459 459
Other changes in Bolivian Hydrocarbons Law(b).......... -- 913 913
Revisions of previous estimates........................ (4) 150 146
Extensions, discoveries and other additions............ -- 840 840
Production............................................. (10) (214) (224)
Purchases of minerals in-place......................... 188 -- 188
------- ------- -------
December 31, 1996......................................... 182 3,744 3,926
Revisions of previous estimates........................ (5) 349 344
Extensions and discoveries............................. 87 -- 87
Production............................................. (43) (189) (232)
Purchases of minerals in-place......................... 430 1,301 1,731
------- ------- -------
December 31, 1997 (c)..................................... 651 5,205 5,856
======= ======= =======
NET PROVED DEVELOPED OIL RESERVES (thousands of barrels)
December 31, 1994......................................... -- 1,627 1,627
December 31, 1995......................................... 4 1,407 1,411
December 31, 1996......................................... 126 2,291 2,417
December 31, 1997 (c)..................................... 296 3,137 3,433
</TABLE>
- ---------------
(a) The Company is required to file annual estimates of its proved reserves with
the Department of Energy. Such filings have been consistent with the
information presented herein.
(b) Under a new Hydrocarbons Law passed by the Bolivian government in 1996, the
Company converted its Contracts of Operation for Block 18 and Block 20 into
four Shared Risk Contracts, which, among other matters, extend the Company's
term of operation, provide more favorable acreage relinquishment terms and
provide for a more favorable royalty and tax structure.
(c) No major discovery or adverse event has occurred since December 31, 1997
that would cause a significant change in net proved reserve volumes.
* * * * * *
F-36
<PAGE> 175
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Stockholders of BHP Petroleum Americas Refining Inc.
and BHP Petroleum South Pacific Inc.:
We have audited the accompanying combined balance sheets of BHP Petroleum
Americas Refining Inc. and BHP Petroleum South Pacific Inc. (the Company) as of
May 31, 1997 and 1996, and the related combined statements of operations,
stockholders' equity and cash flows for each of the three years in the period
ended May 31, 1997. These financial statements are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the combined financial position of BHP Petroleum
Americas Refining Inc. and BHP Petroleum South Pacific Inc. as of May 31, 1997
and 1996, and the combined results of their operations and their cash flows for
each of the three years in the period ended May 31, 1997, in conformity with
generally accepted accounting principles.
/s/ ARTHUR ANDERSEN LLP
Honolulu, Hawaii
March 31, 1998
F-37
<PAGE> 176
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED STATEMENTS OF OPERATIONS
(IN THOUSANDS)
<TABLE>
<CAPTION>
YEARS ENDED MAY 31,
------------------------------------
1995 1996 1997
---------- ---------- ----------
<S> <C> <C> <C>
REVENUES
Sales and other revenue -- trade....................... $ 752,044 $ 741,631 $ 886,380
Sales and other revenue -- affiliates.................. 79,908 72,992 111,258
Other income........................................... 750 905 211
---------- ---------- ----------
Total Revenue.................................. 832,702 815,528 997,849
---------- ---------- ----------
OPERATING COSTS AND EXPENSES
Cost of sales.......................................... 720,597 711,131 881,991
Operating and selling.................................. 42,148 43,661 43,363
Depreciation and amortization.......................... 27,745 29,507 30,596
Refinery assets write-down to fair value (Note 5)...... -- -- 88,813
Goodwill write-off (Notes 2 and 5)..................... -- -- 30,351
---------- ---------- ----------
Total Operating Costs and Expenses............. 790,490 784,299 1,075,114
---------- ---------- ----------
OPERATING INCOME (LOSS).................................. 42,212 31,229 (77,265)
General and administrative............................. (22,319) (21,238) (24,731)
Interest............................................... (11,274) (9,887) (9,976)
Capitalized interest................................... 857 765 1,269
---------- ---------- ----------
INCOME (LOSS) BEFORE INCOME TAXES........................ 9,476 869 (110,703)
Income tax benefit (provision)........................... (4,673) (1,474) 30,125
---------- ---------- ----------
NET INCOME (LOSS)........................................ $ 4,803 $ (605) $ (80,578)
========== ========== ==========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-38
<PAGE> 177
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED BALANCE SHEETS
(DOLLARS IN THOUSANDS)
<TABLE>
<CAPTION>
AS OF MAY 31,
--------------------
1996 1997
-------- --------
<S> <C> <C>
ASSETS
CURRENT ASSETS
Cash...................................................... $ 1,043 $ 1,420
Accounts receivable, net.................................. 43,913 47,675
Due from affiliates -- trade.............................. 10,742 9,906
Due from affiliates -- other.............................. 22,369 22,115
Inventories............................................... 52,354 83,864
Other current assets...................................... 5,712 4,802
-------- --------
Total current assets.............................. 136,133 169,782
-------- --------
PROPERTY, PLANT AND EQUIPMENT, net of accumulated
depreciation and amortization (Note 5).................... 378,235 303,442
-------- --------
NON-CURRENT ASSETS
Goodwill, net of accumulated amortization (Note 5)........ 32,931 --
Other..................................................... 7,653 4,220
-------- --------
Total non-current assets.......................... 40,584 4,220
-------- --------
Total Assets...................................... $554,952 $477,444
======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Cash overdraft............................................ $ 6,668 $ 6,840
Accounts payable.......................................... 7,557 12,287
Due to affiliates -- trade................................ 4,587 29,933
Capital lease obligations, current portion................ 685 1,055
Accrued liabilities....................................... 13,213 20,782
-------- --------
Total current liabilities......................... 32,710 70,897
-------- --------
NOTES PAYABLE TO AFFILIATE -- noncurrent.................... 145,000 145,000
CAPITAL LEASE OBLIGATIONS, net of current portion........... 5,917 9,361
DEFERRED INCOME TAXES....................................... 66,014 30,659
OTHER LIABILITIES........................................... 31,746 28,540
COMMITMENTS AND CONTINGENCIES (Note 14)
STOCKHOLDERS' EQUITY
Common stock, no par value, 1,000,500 shares authorized,
issued and outstanding................................. 8,208 8,208
Additional paid-in capital................................ 52,362 52,362
Retained earnings:
BHP Petroleum Americas Refining Inc.................... 204,205 122,378
BHP Petroleum South Pacific Inc........................ 8,790 10,039
-------- --------
Total stockholders' equity........................ 273,565 192,987
-------- --------
Total Liabilities and Stockholders' Equity........ $554,952 $477,444
======== ========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-39
<PAGE> 178
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED STATEMENTS OF STOCKHOLDERS' EQUITY
(DOLLARS IN THOUSANDS)
<TABLE>
<CAPTION>
COMMON STOCK ADDITIONAL TOTAL
------------------- PAID-IN RETAINED STOCKHOLDERS'
SHARES AMOUNT CAPITAL EARNINGS EQUITY
--------- ------- ---------- -------- -------------
<S> <C> <C> <C> <C> <C>
Balance May 31, 1994
BHP Petroleum Americas Refining
Inc............................... 500 $ 8,008 $ 42,000 $200,219 $250,227
BHP Petroleum South Pacific Inc...... 1,000,000 200 10,362 8,578 19,140
--------- ------- -------- -------- --------
Total........................ 1,000,500 8,208 52,362 208,797 269,367
Net income........................... -- -- -- 4,803 4,803
--------- ------- -------- -------- --------
Balance May 31, 1995................... 1,000,500 8,208 52,362 213,600 274,170
Net loss............................. -- -- -- (605) (605)
--------- ------- -------- -------- --------
Balance May 31, 1996................... 1,000,500 8,208 52,362 212,995 273,565
Net loss............................. -- -- -- (80,578) (80,578)
--------- ------- -------- -------- --------
Balance, May 31, 1997.................. 1,000,500 $ 8,208 $ 52,362 $132,417 $192,987
========= ======= ======== ======== ========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-40
<PAGE> 179
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
<TABLE>
<CAPTION>
YEARS ENDED MAY 31,
------------------------------
1995 1996 1997
-------- -------- --------
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)........................................... $ 4,803 $ (605) $(80,578)
Adjustments to reconcile net income (loss) to net cash
provided by operating activities:
Refinery assets write-down to fair value.................. -- -- 88,813
Goodwill write-off........................................ -- -- 30,351
Depreciation and amortization............................. 27,745 29,507 30,596
Deferred income taxes..................................... (6,067) 285 (35,355)
Changes in:
Accounts receivable, net............................... (44,397) 7,767 (3,762)
Due from affiliates, trade and other................... 29,368 (786) 1,090
Inventories............................................ (6,803) 18,916 (31,510)
Other assets........................................... 2,569 (8,903) 4,343
Accounts payable and accrued liabilities............... 13,644 (4,343) 12,471
Due to affiliates, trade............................... (1,274) (15,106) 25,346
Other liabilities...................................... 4,499 4,008 (3,206)
-------- -------- --------
Net cash provided by operating activities................. 24,087 30,740 38,599
CASH FLOWS FROM INVESTING ACTIVITIES --
Additions to property plant and equipment................. (23,461) (29,568) (37,467)
CASH FLOWS FROM FINANCING ACTIVITIES --
Repayment of principal on capital leases.................. (527) (654) (755)
-------- -------- --------
Net increase in cash........................................ 99 518 377
Cash, beginning of period................................... 426 525 1,043
-------- -------- --------
Cash, end of period......................................... $ 525 $ 1,043 $ 1,420
======== ======== ========
Supplemental disclosures:
Acquisition of equipment under capital lease.............. $ -- $ 1,900 $ 4,569
Fixed assets from parent company, at book value........... $ -- $ 7,540 $ --
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-41
<PAGE> 180
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(DOLLARS IN THOUSANDS)
1. ORGANIZATION
BHP Petroleum Americas Refining Inc. (BHPPAR), a Hawaii corporation, and
BHP Petroleum South Pacific Inc. (BHPPSP), a California corporation,
collectively referred to as "the Company," are affiliated companies and
wholly-owned indirect subsidiaries of The Broken Hill Proprietary Company
Limited (BHP), an Australian company. All capital and financing requirements of
the Company are provided for by BHP, except for capital and operating leases.
BHPPAR operates an oil refinery, product storage and distribution
facilities, and retail gasoline stations in the state of Hawaii. Crude oil is
purchased through other BHP affiliates and shipped to Hawaii by tanker. Refined
product exports usually are sold through other BHP affiliates. BHPPSP is a
petroleum products marketer in American Samoa, and operates the government-owned
product storage and distribution facilities. BHPPSP purchases most of its
refined products from BHPPAR.
The Companies were part of a consolidated group, Pacific Resources, Inc.
and Subsidiaries (PRI), purchased by BHP in March 1989. The purchase price was
allocated to assets and liabilities based on fair values at the acquisition
date. The purchase price in excess of fair values was reported as goodwill until
May 1997 when the refinery assets were written down to estimated fair value and
the unamortized goodwill was written off (see Note 5).
There have been changes in the former PRI group since 1989: certain
subsidiaries were liquidated, others were merged or became subsidiaries of other
BHP affiliates. In 1995 two affiliates, BHP Petroleum Americas Terminals Inc.
(Terminals), and BHP Petroleum Americas Gas Express Inc. (Gas Express), were
merged into BHPPAR. In connection with this reorganization, all employees of
Terminals, Gas Express and parent company, BHP Hawaii Inc., became employees of
BHPPAR. The 1995 financial statements reflect the results of operations of these
combined entities, consistent with the presentation in 1996 and 1997.
2. SIGNIFICANT ACCOUNTING POLICIES
Combined Financial Statements -- The combined financial statements include
the accounts of BHPPAR and BHPPSP. These companies are combined to present the
financial position and results of operations of BHP's downstream petroleum
refining and marketing business. The combined financial statements have been
prepared using the historical costs and results of operations of the affiliated
entities. There were no significant differences in accounting methods or their
application among the combining entities. All significant intercompany balances
and transactions between the combined entities are eliminated.
Use of Estimates and Presentation -- Preparation of the combined financial
statements, in conformity with generally accepted accounting principles,
requires management to make estimates and assumptions which affect the amounts
of assets and liabilities, and disclosure of contingencies at the date of the
financial statements, and the reported amounts of revenues and expenses during
the reporting periods. Actual results could differ from these estimates.
Financial Instruments -- The carrying amounts of financial instruments,
including cash, accounts receivable, accounts payable, and certain other current
liabilities, approximate fair value because of the short maturity of these
instruments. The carrying amounts of the Company's long-term notes payable and
other obligations approximate the Company's estimate of fair values of such
items.
Hedging Activities -- The Company periodically enters into hedging
arrangements through BHP affiliates to manage petroleum price risks and not for
speculative purposes. Gains and losses from hedging are recognized in income
when the hedged transaction occurs. Historically, gains and losses from hedging
transactions have not been material.
F-42
<PAGE> 181
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
Inventories -- Crude oil and refined products are valued at the lower of
cost or market (net realizable value). Cost is determined primarily on the
last-in, first-out (LIFO) basis. Other inventories held for sale, materials and
supplies are stated at the lower of average cost, not in excess of market.
Property, Plant and Equipment -- Property, plant and equipment is stated at
cost. Major replacements, renewals and improvements are capitalized.
Maintenance, repairs and replacements, which do not improve or extend the lives
of assets, are charged to expense. Depreciation and amortization, including
amortization of assets under capital leases, are computed using the
straight-line method over estimated useful lives or lease terms, if shorter.
Estimated useful lives range up to 20 years for buildings and up to 25 years for
plant and equipment.
Refinery Maintenance Turnaround Costs -- The costs of refinery unit
shutdown and maintenance turnaround costs are included in other assets and
amortized over the estimated period of benefit, generally one to three years,
depending on the process unit.
Goodwill -- Goodwill represents BHP's purchase price in excess of the fair
values of net BHPPAR assets acquired in March 1989, after providing noncurrent
deferred tax liabilities on the difference between the assets' fair values and
their income tax basis. Goodwill was amortized on a straight-line, 20 year rate
until the goodwill was determined to be without further value and was written
off in May 1997 (see Note 5).
Income Taxes -- Deferred tax assets and liabilities are recognized for
future income tax effects of temporary differences between financial statement
carrying amounts and the related income tax bases of assets and liabilities.
Deferred income tax assets and liabilities measurements are based on enacted tax
rates expected to apply when the temporary differences are expected to be
settled. The effect of tax rate changes on deferred tax assets and liabilities
is recognized when rate changes are enacted.
Income taxes are computed and recorded as if each company were filing
separate tax returns, although BHPPAR and BHPPSP are included in different
federal and state consolidated income tax returns which include other BHP
companies in the affiliated groups. Current income tax liabilities or refunds
are settled with BHP through intercompany accounts.
Environmental Expenditures -- Environmental expenditures for current
operations are expensed or capitalized, as appropriate. Expenditures are
capitalized if they extend the useful lives of assets, increase capacity, or
mitigate or prevent environmental contamination. Expenditures are expensed if
they are for existing conditions caused by past operations, and if the
expenditures will not contribute to future revenue generation. Liabilities are
recorded when environmental assessments and/or remedial efforts are probable and
when costs can be estimated reasonably. Such amounts are based on the estimated
timing and extent of remedial actions required by regulatory agencies,
experience gained from other sites where assessments and remediation have been
completed, and the amount of the Company's estimated liability, considering
proportional liability and financial abilities of other responsible parties.
Adjustments to accrued liabilities are made as changes in conditions and
estimated costs become known.
Pension Plans and Other Post-Employment Benefits -- Pension costs are
accounted for in conformity with Statements of Financial Accounting Standards
No. 87 and 88. Funding is based on required contributions under the Employee
Retirement Income Security Act of 1974. Other post-employment benefits,
primarily medical insurance, are accounted for in conformity with Statement of
Financial Accounting Standards No. 106.
3. RECEIVABLES
The Company operates in a single industry, marketing refined petroleum
products in a limited geographic area, primarily Hawaii and American Samoa. The
markets are subject to economic and industry changes,
F-43
<PAGE> 182
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
including changes in market prices and sources of supply. Concentration of
credit risk in trade receivables is limited by the numbers and variety of
customers. In October 1997, BHP sold a Hawaii gas services subsidiary (the Gas
Company) to an unrelated company. The Gas Company continues to purchase naphtha
and propane (LPG) from the refinery. Receivables from the Gas Company amounted
to $3,243 and $3,886 at May 31, 1996 and 1997, respectively.
BHPPSP operates the government-owned fuel storage facilities and markets to
a wide range of customers in American Samoa. The facilities management contract
expired in 1997 and was awarded to a competitor. BHPPSP has contested the award,
but there is no assurance that the company will be able to continue as the
facilities operator and/or as a marketer in American Samoa. Transfer of
operations to a competitor could increase the collection risk of receivables in
that market. BHPPSP's receivables, net of allowance for doubtful accounts,
amounted to $3,331 and $4,273 at May 31, 1996 and 1997, respectively.
The company performs on-going credit evaluations of its customers financial
condition, and in some circumstances requires prepayment or letters of credit.
The allowance for doubtful accounts is included in the combined balance sheets
as a reduction of receivables. The allowance for doubtful accounts as of May 31,
1995, 1996 and 1997, was $1,561, $734 and $698, respectively.
4. INVENTORIES
Inventories at May 31 consisted of:
<TABLE>
<CAPTION>
1996 1997
------- -------
<S> <C> <C>
Crude oil and refined products.............................. $42,107 $73,601
Merchandise and packaged petroleum products................. 896 1,243
Materials and supplies...................................... 9,351 9,020
------- -------
Total inventories........................................... $52,354 $83,864
======= =======
</TABLE>
At May 31, 1996 and 1997, crude oil and product inventories at LIFO cost
amounting to $41.0 million and $71.5 million, respectively, were below current
cost by approximately $10.7 million and $7.0 million, respectively.
5. PROPERTY, PLANT AND EQUIPMENT, GOODWILL, AND RELATED WRITE-DOWNS
Principal assets include the oil refinery, its buildings and its property
site on the island of Oahu. The Company owns pipelines connecting the refinery
to an off-shore, single-point mooring, to a barge harbor near the refinery, and
to Honolulu International Airport and Honolulu Harbor. Marketing facilities
include product storage and distribution terminals on the islands of Maui and
Hawaii, as well as retail gas stations.
In 1997 BHP developed a plan to sell the Company, engaged an investment
advisor, completed an appraisal of assets, and began discussions with potential
buyers. Management determined that net book value of refinery assets had been
impaired based in part on the appraisal. The refinery property, plant and
equipment were written down to estimated fair value in May 1997, based on an
evaluation of these assets, related operating results, and in accordance with
provisions of Statement of Financial Accounting Standards No. 121. The
write-down, net of accumulated depreciation, amounted to $88.8 million ($54.2
million after a $34.6 million reduction in deferred income taxes), as summarized
below. BHP reached an agreement in March 1998 to sell the Company, and as a
result of the sale, the Company anticipates recognizing an estimated loss of
approximately $120-125 million, in addition to the loss recognized in May 1997
(see
F-44
<PAGE> 183
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
Note 15). Substantially all of the loss is expected to be allocated to a further
reduction in the fair value of the property, plant and equipment.
<TABLE>
<CAPTION>
1996 1997
--------- ---------
<S> <C> <C>
Land and buildings.......................................... $ 67,708 $ 70,451
Plant and equipment, including capital leases............... 548,067 582,076
--------- ---------
Total before revaluation write-down......................... 615,775 652,527
Accumulated depreciation and amortization................... (237,540) (260,272)
--------- ---------
Property, plant and equipment, net before write-down........ 378,235 392,255
--------- ---------
Less write-down to estimated fair value:
Land and buildings........................................ -- (23,451)
Plant and equipment....................................... -- (325,634)
Accumulated depreciation and amortization................. -- 260,272
--------- ---------
Net write-down to estimated fair value............ -- (88,813)
--------- ---------
Property, plant and equipment, net.......................... $ 378,235 $ 303,442
========= =========
</TABLE>
In connection with management's determination that the carrying amount of
refinery assets had become impaired, it was also determined that goodwill had no
continuing value. Therefore, the remaining net goodwill of $30,351 ($51,636, net
of accumulated amortization of $21,285) was also written off in May 1997. Annual
goodwill amortization expense included in statements of operations was $2,580
for each of the three years ended May 31, 1997.
6. LEASES
The company leases equipment and some properties under various lease
agreements covering periods through 2024. Properties include the pipeline
corridor from the refinery to Honolulu International Airport and Honolulu
Harbor, as well as land underlying terminal facilities and most of the gas
stations. The Company also uses product terminals owned by others, including
deliveries at Honolulu Harbor, Honolulu International Airport, and all sales in
American Samoa. Rent, through-put fees, and storage fees are paid for use of
these facilities. Certain operating leases contain provisions for renegotiation
or escalation of rents based on operating costs or usage. Rent expense for
operating leases, including leases with terms of a month or less, was $13,696 in
1995, $13,125 in 1996 and $13,330 in 1997.
Capital leases are for tugs and barges used in transportation of petroleum
products within Hawaii. Cost and accumulated amortization of capitalized leased
assets at May 31 amounted to:
<TABLE>
<CAPTION>
1996 1997
------- -------
<S> <C> <C>
Capitalized leases -- cost.................................. $12,204 $15,023
Accumulated amortization.................................... (5,965) (5,123)
------- -------
Capitalized leases included in property -- net.............. $ 6,239 $ 9,900
======= =======
</TABLE>
F-45
<PAGE> 184
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
Minimum lease commitments under non-cancelable leases (excluding leases
with terms of one year or less) at May 31, 1997 are summarized below:
<TABLE>
<CAPTION>
FISCAL OPERATING CAPITAL
YEAR LEASES LEASES
- ------------------------------------------------------------ --------- -------
<S> <C> <C>
1998........................................................ $ 12,186 $ 2,005
1999........................................................ 10,763 1,884
2000........................................................ 9,394 1,677
2001........................................................ 9,441 1,634
2002........................................................ 8,221 1,468
Thereafter.................................................. 96,027 6,659
-------- -------
Total minimum lease payments................................ $146,032 15,327
========
Less amount representing interest........................... (4,911)
-------
Present value of net minimum lease payments................. 10,416
Less current portion........................................ (1,055)
-------
Noncurrent portion.......................................... $ 9,361
=======
</TABLE>
7. ACCRUED LIABILITIES
Accrued current liabilities at May 31 included the following:
<TABLE>
<CAPTION>
1996 1997
------- -------
<S> <C> <C>
Environmental costs......................................... $ 3,190 $ 3,950
Accrued employee compensation............................... 5,502 10,768
Taxes, other than income taxes.............................. 4,239 5,908
Other accrued liabilities................................... 282 156
------- -------
Total accrued liabilities, current.......................... $13,213 $20,782
======= =======
</TABLE>
8. NOTES PAYABLE TO AFFILIATE
Noncurrent debt consists of two unsecured promissory notes totaling $145
million, payable to BHPPAR's parent company, BHP Hawaii Inc. The notes are
payable 395 days from demand, and interest is payable at the monthly average
short-term Applicable Federal Rate, as determined under Internal Revenue Code
Sec. 1274(d). Interest rates ranged from 5.56% to 7.43% in 1995, 5.05% to 6.37%
in 1996, and 5.63% to 6.23% in 1997. The rates for May 1996 and 1997 were 5.76%
and 6.23%, respectively. Interest is paid as accrued through settlement of
inter-company accounts. Interest expense on the notes was $9,415 in 1995, $8,364
in 1996, and $8,734 in 1997.
9. INCOME TAXES
The income tax provision (benefit) for the three years ended May 31, 1997,
included:
<TABLE>
<CAPTION>
1995 1996 1997
------- ------ --------
<S> <C> <C> <C>
Current income tax provision.......................... $10,738 $1,990 $ 5,285
Deferred tax benefit.................................. (6,065) (516) (35,410)
------- ------ --------
Total income tax provision (benefit).................. $ 4,673 $1,474 $(30,125)
======= ====== ========
</TABLE>
F-46
<PAGE> 185
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
The deferred income tax benefit in 1997 includes the deferred tax effect of
the fair value write-down of refinery property, plant and equipment.
The following table reconciles taxes on income at the normal 35% Federal
income tax rate with the effective tax rate:
<TABLE>
<CAPTION>
1995 1996 1997
------ ------ ---------
<S> <C> <C> <C>
Earnings (loss) before income taxes................... $9,476 $ 869 $(110,703)
------ ------ ---------
Tax provision (benefit) at U.S. corporate tax rate.... $3,317 $ 304 $ (38,746)
Effect of:
Write-off / amortization of goodwill................ 900 903 11,526
State income taxes, net of Federal tax effects...... 470 149 (3,027)
Other............................................... (14) 118 122
------ ------ ---------
Income tax provision (benefit)........................ $4,673 $1,474 $ (30,125)
====== ====== =========
Effective combined income tax rate.................... 49.3% 169.6% 27.2%
====== ====== =========
</TABLE>
The effective tax rates are significantly different than "normal" because
of the amortization and write-off of goodwill related to BHP's 1989 acquisition
of BHPPAR.
Deferred income tax liabilities and assets, resulting from timing
differences, as of May 31, 1996 and 1997:
<TABLE>
<CAPTION>
1996 1997
------- -------
<S> <C> <C>
Deferred Federal tax assets:
Accrued vacation pay, incentive compensation.............. $ 1,824 $ 692
Accrued retirement benefits............................... 4,376 4,417
Environmental provisions.................................. 7,862 7,236
Other..................................................... 895 995
------- -------
Total deferred tax assets......................... 14,957 13,340
Deferred Federal tax liabilities:
Accelerated depreciation and other property items......... 71,844 39,410
Refinery turn-around costs................................ 2,011 976
Other..................................................... 525 525
------- -------
Total deferred tax liabilities.................... 74,380 40,911
------- -------
Net Federal deferred tax liability.......................... 59,423 27,571
Net State deferred tax liability............................ 6,591 3,088
------- -------
Deferred income tax liability -- net........................ $66,014 $30,659
======= =======
</TABLE>
10. RETIREMENT PLANS
Employees are covered by a qualified noncontributory defined benefit
pension plan. BHPPAR and BHPPSP participate with many other BHP affiliates in
the BHP (USA) Pension Plan, and the plan's actuary allocates assets and
liabilities to the participating entities, as well as determining annual costs
and recommended contributions. The plan's benefit formula is a final-pay
formula. The plan funding policy is to fund a contribution of at least the
minimum funding requirement, but no more than the maximum tax-deductible
contribution.
The following plan information covers all the employees of the Company, as
well as certain employees and retirees of affiliates which were merged into
BHPPAR or disposed of during the three years ended
F-47
<PAGE> 186
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
May 31, 1997. Plan assets exceeded projected benefit obligations, with respect
to BHPPAR and BHPPSP, at May 31, 1996 and 1997. The following tables present
pension expense, funded status and major actuarial assumptions used to determine
amounts.
<TABLE>
<CAPTION>
NET PERIODIC PENSION COST 1995 1996 1997
------------------------- ------- ------- -------
<S> <C> <C> <C>
Service cost.......................................... $ 1,330 $ 1,530 $ 1,550
Interest cost......................................... 1,420 1,470 1,660
Actual return on plan assets.......................... (2,600) (3,000) (4,920)
Net amortization and deferral......................... 1,381 1,521 3,061
------- ------- -------
Net periodic pension cost............................. $ 1,531 $ 1,521 $ 1,351
======= ======= =======
</TABLE>
<TABLE>
<CAPTION>
FUNDED STATUS OF PENSION PLANS AS OF MAY 31 1996 1997
------------------------------------------- ------- -------
<S> <C> <C>
Actuarial present value of accumulated benefit obligation:
Vested.................................................... $13,670 $14,380
Total..................................................... $16,490 $17,610
------- -------
Projected benefit obligation................................ $22,060 $24,420
Plan assets at fair value................................... 22,540 27,120
------- -------
Plan assets in excess of projected benefit obligation....... 480 2,700
Unrecognized net gain....................................... (2,590) (4,800)
Unrecognized prior service cost............................. 1,093 1,002
------- -------
Accrued net pension liability............................... $(1,017) $(1,098)
======= =======
</TABLE>
The accrued net pension liability is included in other liabilities
(noncurrent) in the accompanying balance sheets.
<TABLE>
<CAPTION>
1995 1996 1997
---- ---- ----
<S> <C> <C> <C>
Discount rate............................................... 8.00% 7.75% 7.75%
Rate of increase in future compensation levels.............. 5.00 5.00 5.00
Expected long-term rate of return on plan assets............ 8.50 8.50 8.50
</TABLE>
In addition to the defined benefit plan, the Company is a participating
sponsor in a defined contribution plan. The BHP Retirement Savings Plan (RSP) is
a deferred compensation plan which covers employees of the Company and other BHP
entities in the U.S. The Company matches and contributes an amount equal to each
employee's contribution up to 6 percent of the employee's salary and incentive
compensation. Plan contributions charged to expense amounted to $1,071, $1,222
and $1,421 in 1995, 1996 and 1997, respectively.
Liabilities also are accrued for supplemental retirement benefits for
executives. The unfunded liabilities and expense are actuarially determined.
Payments are made for vested benefits after retirement.
11. OTHER RETIREMENT BENEFITS
Certain medical and life insurance benefits are provided for qualified
retirees and their qualified dependents. Employees who retire at ages 55-61 with
at least 15 years of continuous service, or who retire at age 62, or later, with
at least 10 years of continuous service, become eligible for these benefits. The
health care plan is contributory with retiree contributions adjusted
periodically. The life insurance plan is noncontributory. Plan expense and
liabilities are accrued as actuarially determined and funded on a pay-as-you-go
basis. The
F-48
<PAGE> 187
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
following tables present the composition of post-retirement benefit expense and
the accumulated post-retirement benefit obligation.
<TABLE>
<CAPTION>
COMPONENTS OF NET PERIODIC POST-RETIREMENT BENEFIT COST 1995 1996 1997
------------------------------------------------------- ---- ---- ----
<S> <C> <C> <C>
Service cost................................................ $108 $100 $ 83
Interest cost on accumulated benefit obligation............. 601 528 424
Amortization of unrecognized net transition asset........... (48) (48) (48)
Amortization of unrecognized (gain) loss.................... 8 -- (78)
---- ---- ----
Net periodic post-retirement benefit cost................... $669 $580 $381
==== ==== ====
</TABLE>
<TABLE>
<CAPTION>
ACCRUED POST-RETIREMENT BENEFIT OBLIGATION AS OF MAY 31 1996 1997
------------------------------------------------------- ------ ------
<S> <C> <C>
Retirees and beneficiaries.................................. $4,742 $4,553
Active participants eligible to retire...................... 264 282
Other active participants................................... 733 873
------ ------
Total post-retirement benefit obligation.................... 5,739 5,708
Unrecognized transition asset............................... 776 728
Unrecognized gain........................................... 1,614 1,441
------ ------
Accrued post-retirement benefit obligation.................. $8,129 $7,877
====== ======
</TABLE>
The accrued obligation is included in other liabilities (noncurrent) in the
accompanying balance sheets. Amounts to be paid during the next twelve months
are included in current liabilities.
The weighted average rate of increase in the per capita cost of covered
health care benefits was assumed to be 8% for 1997, decreasing by 1/2% per year
to 5.5% in 2002 and thereafter. A 1% increase in the health care cost trend rate
would increase the accumulated post-retirement benefit obligation by $149 at May
31, 1997, and the net periodic service and interest cost by $13 for the year.
Actuarial assumptions used to measure the accrued post-retirement obligation at
May 31, 1995, 1996 and 1997 included a discount rate of 7.75% and a compensation
rate increase of 6%.
12. RELATED PARTY BALANCES AND TRANSACTIONS
The Company enters into transactions with BHP-affiliated companies
primarily for petroleum operations and general financing activities. Crude oil
is purchased through BHP Petroleum affiliates in the U.S., Australia and
Singapore. Crude oil transportation costs are either included in the purchase
price or paid to an affiliated BHP Transport company. Export products are sold
through BHP Petroleum affiliates. Amounts due to and from BHP-affiliated
companies as of May 31 were:
<TABLE>
<CAPTION>
1996 1997
-------- --------
<S> <C> <C>
Due from affiliates:
Current -- trade receivables.............................. $ 10,742 $ 9,906
Current -- other.......................................... 22,369 22,115
Due to affiliates:
Current -- trade payables................................. 4,587 29,933
Noncurrent notes payable, interest at variable rate......... 145,000 145,000
</TABLE>
F-49
<PAGE> 188
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
Transactions with BHP-affiliated companies for the three years ended May
31, 1997 were:
<TABLE>
<CAPTION>
1995 1996 1997
-------- -------- --------
<S> <C> <C> <C>
Revenues:
Sales and other revenue............................ $ 79,908 $ 72,992 $111,258
Operating Costs and Expenses:
Petroleum purchases, including freight............. 575,175 584,714 614,076
Guarantee fees, included in operating costs........ 1,213 1,539 617
Interest on noncurrent promissory notes............ 9,415 8,364 8,734
Securitization fees, included in interest.......... 1,287 -- --
</TABLE>
Sales of refined products to BHP affiliates are negotiated with reference
to current published market prices. Sales include export cargoes marketed
primarily in Asia. Also, naphtha and LPG are sold to a Hawaii gas utility
affiliate (the Gas Company) under term contracts. BHP sold the Gas Company to an
unrelated company effective October 31, 1997 (see Note 15).
Domestic (Alaskan North Slope) crude oil is purchased from a BHP Petroleum
affiliate at their cost, net of their price hedging transactions. BHPPAR also
imports crude oil, primarily from Australia and Asia, under term agreements with
BHP Petroleum affiliates, and purchase prices are determined by a formula using
current published market prices.
13. FUTURES CONTRACTS
BHPPAR has a term agreement with a third-party customer for the sale of
physical product in exchange for futures contracts (plus a cash location/quality
differential), which are settled through a BHP Petroleum affiliate. The futures
contracts are sold ratably over each month, and proceeds from selling the
futures contracts at current market prices (plus the cash differential)
determine the sales value of product delivered during the month. Futures
contracts at May 31, 1996 and 1997, are summarized below (amounts in 000's):
<TABLE>
<CAPTION>
1996 1997
--------- ---------
<S> <C> <C>
Contract barrels............................................ 250 240
Contract amounts............................................ $ 5,597 $ 5,645
Unrealized gains (losses)................................... $ (257) $ (19)
Maturity dates.............................................. June 1996 June 1997
</TABLE>
14. COMMITMENTS AND CONTINGENCIES
The Company is party to litigation and claims in the normal course of
business. The outcome of individual matters is not predictable. However,
management believes that the ultimate resolution of all of these matters, after
considering insurance coverages, is not likely to have a material adverse effect
on the Company's combined financial statements.
Environmental
The Company's operations are subject to various Federal and state
environmental laws and regulations. The Company has received notices of
violation or potential liability from the U.S. Environmental Protection Agency
(EPA), the State of Hawaii Department of Health (HDOH) and private parties
relating to various environmental matters associated with the Company's
ownership and/or operations of its assets. Generally, the timing of liability
accruals corresponds with the completion of remedial investigations or
feasibility studies, and are adjusted as necessary. Although the amount of
future environmental expenditures cannot be
F-50
<PAGE> 189
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
determined with certainty, Company management believe that compliance with
present laws will not have a material adverse effect on its financial
statements. Environmental provisions as of May 31 were as follows:
<TABLE>
<CAPTION>
1996 1997
------- -------
<S> <C> <C>
Accrued liabilities -- current.............................. $ 3,190 $ 3,950
Other liabilities -- noncurrent............................. 19,785 16,724
------- -------
Total....................................................... $22,975 $20,674
======= =======
</TABLE>
Total environmental expense, including provisions, charged to cost of sales
and operating expense, amounted to $9,003, $7,198 and $4,936 in 1995, 1996, and
1997, respectively.
Refinery -- Based on an inspection conducted by a U.S. EPA consultant, the
EPA issued a Notice of Violation (NOV) in June 1997 against BHP Hawaii and
BHPPAR pursuant to Section 311 of the Clean Water Act (CWA). The NOV alleged
violations of the Spill Prevention, Control and Countermeasures (SPCC)
regulations of the CWA. The Company has submitted information in response to EPA
requests. The EPA has subsequently dropped its allegations relating to the oil
releases and the parties remain engaged in settlement discussions over issues
relating to the refinery's SPCC plan.
In 1993, BHPPAR settled an administrative complaint filed by the EPA in May
1991. The complaint alleged various Resource Conservation and Recovery Act
(RCRA) violations at the refinery involving surface impoundment closure and
groundwater monitoring requirements. The settlement, embodied in a Consent
Agreement/Final Order (dated July 1993) required BHPPAR to pay a fine (which was
satisfied); conduct certain groundwater monitoring tasks and closure of the
surface impoundments (which have been done and for which final EPA approval was
received in January 1996); complete a supplemental environmental project (which
has been done); and investigate and, if required, implement Corrective Action
under RCRA in and about the refinery site (which is in progress). A report of
the investigation results, dated March 1997, was submitted to the EPA. The
majority of the costs related to the closure plans have been expended. At May
31, 1997, $1.9 million remained in other liabilities to provide for estimated
post-closure monitoring costs over a 30 year period.
Under authority of the Emergency Planning and Community Right-to-Know Act
(EPCRA), the EPA issued a Request for Information relating to past releases of
reportable quantities of regulated EPCRA substances and oil. Pertinent data and
documentation were transmitted to the EPA. A Notice of Violation (NOV) was
issued in June 1997 against BHP Hawaii and BHPPAR, alleging eight violations.
The Company has submitted further information in response. The matter remains
subject to EPA review. No penalty amounts have been assessed to date.
Under a permit application and required compliance certification submitted
by BHPPAR pursuant to Title V of the Clean Air Act (CAA), BHPPAR noted several
regulatory requirements that were not being met at the time of submission, and
included a schedule for addressing or correcting these in accordance with
application regulations. BHPPAR has implemented corrective measures to address
the foregoing items in accordance with its proposed compliance schedule. Under
authority of the CAA, the EPA asked for additional information relating to such
past non-compliance matters. BHPPAR provided the information and documents
requested. In 1996 the EPA issued a Finding of Violation (FOV) against BHP
Hawaii and BHPPAR. The parties have engaged in settlement negotiations and no
penalty amount has been assessed. It is not anticipated that any penalty imposed
or settlement concluded will have a material adverse effect on the Company's
financial condition.
Honolulu Harbor -- Properties adjacent to Honolulu Harbor have been
impacted by the conduct of a variety of industrial activities since the
beginning of this century. The HDOH, under the authority of the
F-51
<PAGE> 190
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
Hawaii Environmental Response Law, requested information from various owners and
operators in the area surrounding the harbor to determine the extent of
hydrocarbon contamination. A group of owners and operators, including BHP Hawaii
Inc., on behalf of the Company, have entered into a voluntary agreement with the
HDOH to undertake an initial phase of environmental site investigation in
exchange for certain commitments from the HDOH, including the notification of
additional potentially responsible parties to participate in this activity. A
provision of $600 was accrued for the estimated costs of this initial phase. An
additional $2.8 million was accrued to perform hydrogeological studies and
groundwater monitoring in the vicinity of Pier 29 which was formerly leased and
operated by the Company.
Honolulu International Airport -- As a result of environmental site
assessments commissioned by the State of Hawaii Department of Transportation
(HDOT) in conjunction with the proposed development of properties in the
vicinity of the airport, the HDOT requested that costs be shared among certain
facility owners and operators to remedy an alleged hydrocarbon condition in the
area. At the time of the site assessment, BHPPAR operated certain aboveground
fuel tanks located near the development area. The HDOT subsequently deferred its
development plans indefinitely. BHPPAR sold its interests in the fuel tank
facilities and underlying real property to an adjacent tank farm operator which
continues to operate the facilities. To date no claims or demands have been made
against BHPPAR. The Company has accrued $1.6 million for estimated hydrocarbon
recovery and clean-up costs.
Gas Express Retail Gas Stations -- The Company has sixteen stations which
have been subject to known petroleum product releases. Of these, eight have
received "no further action" determinations from the HDOH, and one has a "no
further action" request pending. Of the remaining stations, one site has been
scheduled for demolition and the reconstruction of a new gas station facility.
Contaminated soil is to be removed at the time of demolition. Another station
has been completely reconstructed and a request for "no further action" status
is in the process of being submitted. Five remaining stations are currently
still being investigated and/or remediated in accordance with regulatory
requirements. The Company is responsible to assure proper closure of the
underground storage tank systems in compliance with regulatory requirements when
each of its stations is eventually taken out of service. As closures occur, the
Company incurs costs for the excavation of soils, the removal and disposal of
tanks, environmental site assessments and media remediation, if necessary, as
well as costs to buy-out unexpired lease commitments and write-off any
unamortized improvements. The Company has prepared cost estimates for the
closure of each site. As of May 31, 1997, total closure costs were estimated to
be $14.3 million, of which $7.7 million has been provided for. Of this amount,
$2.7 million was provided for stations with known or suspected product leakage.
The remainder of the estimated closure costs are being accrued over the
remaining terms of stations' respective leases.
Capital Expenditure Commitments
The Company had capital projects in progress at May 31, 1997, which were
expected to require an additional $11.6 million to complete.
15. SUBSEQUENT EVENTS
Sale of Company to Tesoro Petroleum Corporation -- March 1998
On March 18, 1998, the Company's stockholders entered into a stock sale
agreement with Tesoro Petroleum Corporation (Tesoro), whereby Tesoro will
purchase all of the outstanding common stock of BHPPAR and BHPPSP. The sale is
expected to close by the end of May 1998, subject to regulatory review and other
customary conditions. The price to be paid at closing amounts to $275 million in
cash (including a $5 million escrow deposit). After closing, the cash price will
be increased by the amount that net working capital sold exceeds $100 million,
or reduced by the amount that net working capital is less than $100 million. In
addition, Tesoro will issue an unsecured, non-interest bearing, promissory note
for $50 million payable in
F-52
<PAGE> 191
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
five equal annual installments of $10 million each, beginning in 2009. The note
will provide for earlier payment, depending on earnings performance of the
acquired assets.
The parties will execute a separate environmental agreement at closing,
whereby the selling stockholders will indemnify Tesoro and the Company for
environmental costs arising out of conditions which exist at, or existed prior
to, closing subject to a maximum limit of $9.5 million. The environmental
indemnity will survive for a ten-year period. Certain environmental liabilities
of the Companies will be retained by BHP and are not subject to the $9.5 million
indemnity.
As a result of the sale, the Company anticipates recognizing an estimated
loss of approximately $120-125 million. This estimated loss will increase or
decrease based on results of operations and changes in noncurrent assets and
liabilities through the closing date. Substantially all of the loss is expected
to be allocated to a further reduction in the fair value of the property, plant
and equipment.
Sale of the Gas Company -- October 1997
An affiliated Hawaii company, Gasco, Inc. (the Gas Company), was sold
effective October 31, 1997. The Gas Company provides public utility gas service
and non-utility propane (LPG) to residential and commercial customers throughout
Hawaii. The Gas Company continues to purchase naphtha, for the manufacture of
synthetic natural gas, and liquefied petroleum gas from BHPPAR under term
contracts. Sales to the Gas Company are included in sales to affiliates in the
accompanying statements of operations and in related-party information (see Note
12). Sales to the Gas Company amounted to $21.3 million in 1995, $21.4 million
in 1996, and $21.8 million in 1997.
* * * * * *
F-53
<PAGE> 192
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED STATEMENTS OF OPERATIONS
(UNAUDITED)
(IN THOUSANDS)
<TABLE>
<CAPTION>
SEVEN MONTHS ENDED
DECEMBER 31,
--------------------
1996 1997
-------- --------
<S> <C> <C>
REVENUES
Sales and other revenue -- trade.......................... $520,483 $456,817
Sales and other revenue -- affiliates..................... 61,929 74,684
Other income.............................................. 3 3
-------- --------
Total Revenue..................................... 582,415 531,504
-------- --------
OPERATING COSTS AND EXPENSES
Cost of sales............................................. 504,913 460,310
Operating and selling..................................... 24,190 25,543
Depreciation and amortization (Note 4).................... 16,834 --
-------- --------
Total Operating Costs and Expenses................ 545,937 485,853
-------- --------
OPERATING INCOME............................................ 36,478 45,651
General and administrative................................ (10,325) (10,648)
Interest.................................................. (5,934) (5,802)
Capitalized interest...................................... 749 1,097
-------- --------
INCOME BEFORE INCOME TAXES.................................. 20,968 30,298
Income tax provision........................................ (8,783) (11,876)
-------- --------
NET INCOME.................................................. $ 12,185 $ 18,422
======== ========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-54
<PAGE> 193
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED BALANCE SHEETS
(UNAUDITED)
(DOLLARS IN THOUSANDS)
<TABLE>
<CAPTION>
AS OF DECEMBER 31,
-------------------
1996 1997
-------- --------
<S> <C> <C>
ASSETS
CURRENT ASSETS
Cash...................................................... $ 3,978 $ 2,704
Accounts receivable, net.................................. 59,865 45,044
Due from affiliates -- trade.............................. 7,742 7,096
Due from affiliates -- other.............................. 42,333 4,513
Inventories............................................... 63,682 84,331
Other current assets...................................... 3,700 3,539
-------- --------
Total current assets.............................. 181,300 147,227
-------- --------
PROPERTY, PLANT AND EQUIPMENT, net of accumulated
depreciation and amortization............................. 382,101 331,247
-------- --------
NON-CURRENT ASSETS
Goodwill, net of accumulated amortization (Note 4)........ 31,426 --
Other..................................................... 7,570 3,350
-------- --------
Total non-current assets.......................... 38,996 3,350
-------- --------
Total Assets...................................... $602,397 $481,824
======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Cash overdraft............................................ $ 8,485 $ 4,842
Accounts payable.......................................... 18,610 10,545
Due to affiliates -- trade................................ 29,799 20,485
Capital lease obligations, current portion................ 685 1,007
Accrued liabilities....................................... 12,842 12,667
-------- --------
Total current liabilities......................... 70,421 49,546
-------- --------
NOTES PAYABLE TO AFFILIATE -- noncurrent.................... 145,000 145,000
CAPITAL LEASE OBLIGATIONS, net of current portion........... 5,496 8,751
DEFERRED INCOME TAXES....................................... 62,839 36,086
OTHER LIABILITIES........................................... 32,891 31,032
COMMITMENTS AND CONTINGENCIES (Note 7)
STOCKHOLDERS' EQUITY
Common stock, no par value, 1,000,500 shares authorized,
issued and outstanding................................. 8,208 8,208
Additional paid-in capital................................ 52,362 52,362
Retained earnings:
BHP Petroleum Americas Refining Inc.................... 216,490 140,517
BHP Petroleum South Pacific Inc........................ 8,690 10,322
-------- --------
Total stockholders' equity........................ 285,750 211,409
-------- --------
Total Liabilities and Stockholders' Equity........ $602,397 $481,824
======== ========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-55
<PAGE> 194
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED STATEMENTS OF CASH FLOWS
(UNAUDITED)
(IN THOUSANDS)
<TABLE>
<CAPTION>
SEVEN MONTHS ENDED
DECEMBER 31,
-------------------
1996 1997
-------- --------
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income.................................................. $ 12,185 $ 18,422
Adjustments to reconcile net income to net cash provided by
operating activities:
Depreciation and amortization............................. 16,834 --
Deferred income taxes..................................... (3,175) 5,427
Changes in:
Accounts receivable, net............................... (15,952) 2,631
Due from affiliates, trade and other................... (16,964) 20,412
Inventories............................................ (11,328) (467)
Other assets........................................... 2,095 2,133
Accounts payable and accrued liabilities............... 12,499 (11,855)
Due to affiliates, trade............................... 25,212 (9,448)
Other liabilities...................................... 1,145 2,492
-------- --------
Net cash provided by operating activities................. 22,551 29,747
CASH FLOWS FROM INVESTING ACTIVITIES --
Additions to property plant and equipment................. (19,195) (27,805)
CASH FLOWS FROM FINANCING ACTIVITIES --
Repayment of principal on capital leases.................. (421) (658)
-------- --------
Net increase in cash........................................ 2,935 1,284
Cash, beginning of period................................... 1,043 1,420
-------- --------
Cash, end of period......................................... $ 3,978 $ 2,704
======== ========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-56
<PAGE> 195
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(UNAUDITED)
(DOLLARS IN THOUSANDS)
1. ORGANIZATION
BHP Petroleum Americas Refining Inc. (BHPPAR), a Hawaii corporation, and
BHP Petroleum South Pacific Inc. (BHPPSP), a California corporation,
collectively referred to as "the Company," are affiliated companies and
wholly-owned indirect subsidiaries of The Broken Hill Proprietary Company
Limited (BHP), an Australian company. All capital and financing requirements of
the Company are provided for by BHP, except for capital and operating leases.
BHPPAR operates an oil refinery, product storage and distribution
facilities, and retail gasoline stations in the state of Hawaii. Crude oil is
purchased through other BHP affiliates and shipped to Hawaii by tanker. Refined
product exports usually are sold through other BHP affiliates. BHPPSP is a
petroleum products marketer in American Samoa, and operates the government-owned
product storage and distribution facilities. BHPPSP purchases most of its
refined products from BHPPAR.
The Companies were part of a consolidated group, Pacific Resources, Inc.
and Subsidiaries (PRI), purchased by BHP in March 1989. The purchase price was
allocated to assets and liabilities based on fair values at the acquisition
date. The purchase price in excess of fair values was reported as goodwill until
May 1997 when the refinery assets were written down to estimated fair value and
the unamortized goodwill was written off.
2. BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES
The Company's interim combined financial statements and notes thereto have
been prepared by management without audit. Accordingly, the accompanying
financial statements reflect all adjustments that, in the opinion of management,
are necessary for a fair presentation of results for the periods presented. Such
adjustments are of a normal recurring nature. Certain information and notes
normally included in financial statements prepared in accordance with generally
accepted accounting principles have been condensed or omitted. However,
management believes that the disclosures presented herein are adequate to make
the information not misleading.
Combined Financial Statements -- The combined financial statements include
the accounts of BHPPAR and BHPPSP. These companies are combined to present the
financial position and results of operations of BHP's downstream petroleum
refining and marketing business. The combined financial statements have been
prepared using the historical costs and results of operations of the affiliated
entities. There were no significant differences in accounting methods or their
application among the combining entities. All significant intercompany balances
and transactions between the combined entities are eliminated.
Use of Estimates and Presentation -- Preparation of the combined financial
statements, in conformity with generally accepted accounting principles,
requires management to make estimates and assumptions which affect the amounts
of assets and liabilities, and disclosure of contingencies at the date of the
financial statements, and the reported amounts of revenues and expenses during
the reporting periods. Actual results could differ from these estimates.
Financial Instruments -- The carrying amounts of financial instruments,
including cash, accounts receivable, accounts payable, and certain other current
liabilities, approximate fair value because of the short maturity of these
instruments. The carrying amounts of the Company's long-term notes payable and
other obligations approximate the Company's estimate of fair values of such
items.
Hedging Activities -- The Company periodically enters into hedging
arrangements through BHP affiliates to manage petroleum price risks and not for
speculative purposes. Gains and losses from hedging are
F-57
<PAGE> 196
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
recognized in income when the hedged transaction occurs. Historically, gains and
losses from hedging transactions have not been material.
Inventories -- Crude oil and refined products are valued at the lower of
cost or market (net realizable value). Cost is determined primarily on the
last-in, first-out (LIFO) basis. Other inventories held for sale, materials and
supplies are stated at the lower of average cost, not in excess of market.
Property, Plant and Equipment -- Property, plant and equipment is stated at
cost. Major replacements, renewals and improvements are capitalized.
Maintenance, repairs and replacements, which do not improve or extend the lives
of assets, are charged to expense. In accordance with provisions of Statement of
Financial Accounting Standards No. 121, no depreciation or amortization has been
recorded since May 1997. In previous years, depreciation and amortization,
including amortization of assets under capital leases, were computed using the
straight-line method over estimated useful lives or lease terms, if shorter.
Estimated useful lives range up to 20 years for buildings and up to 25 years for
plant and equipment.
Refinery Maintenance Turnaround Costs -- The costs of refinery unit
shutdown and maintenance turnaround costs are included in other assets and
amortized over the estimated period of benefit, generally one to three years,
depending on the process unit.
Goodwill -- Goodwill represents BHP's purchase price in excess of the fair
values of net BHPPAR assets acquired in March 1989, after providing noncurrent
deferred tax liabilities on the difference between the assets' fair values and
their income tax basis. Goodwill was amortized on a straight-line, 20 year rate
until the goodwill was determined to be without further value and was written
off in May 1997.
Income Taxes -- Deferred tax assets and liabilities are recognized for
future income tax effects of temporary differences between financial statement
carrying amounts and the related income tax bases of assets and liabilities.
Deferred income tax assets and liabilities measurements are based on enacted tax
rates expected to apply when the temporary differences are expected to be
settled. The effect of tax rate changes on deferred tax assets and liabilities
is recognized when rate changes are enacted.
Income taxes are computed and recorded as if each company were filing
separate tax returns, although BHPPAR and BHPPSP are included in different
federal and state consolidated income tax returns which include other BHP
companies in the affiliated groups. Current income tax liabilities or refunds
are settled with BHP through intercompany accounts.
Environmental Expenditures -- Environmental expenditures for current
operations are expensed or capitalized, as appropriate. Expenditures are
capitalized if they extend the useful lives of assets, increase capacity, or
mitigate or prevent environmental contamination. Expenditures are expensed if
they are for existing conditions caused by past operations, and if the
expenditures will not contribute to future revenue generation. Liabilities are
recorded when environmental assessments and/or remedial efforts are probable and
when costs can be estimated reasonably. Such amounts are based on the estimated
timing and extent of remedial actions required by regulatory agencies,
experience gained from other sites where assessments and remediation have been
completed, and the amount of the Company's estimated liability, considering
proportional liability and financial abilities of other responsible parties.
Adjustments to accrued liabilities are made as changes in conditions and
estimated costs become known.
Pension Plans and Other Post-Employment Benefits -- Pension costs are
accounted for in conformity with Statements of Financial Accounting Standards
No. 87 and 88. Funding is based on required contributions under the Employee
Retirement Income Security Act of 1974. Other post-employment benefits,
primarily medical insurance, are accounted for in conformity with Statement of
Financial Accounting Standards No. 106.
F-58
<PAGE> 197
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
3. INVENTORIES
Inventories at December 31 consisted of:
<TABLE>
<CAPTION>
1996 1997
------- -------
<S> <C> <C>
Crude oil and refined products.............................. $53,977 $75,366
Merchandise and packaged petroleum products................. 868 1,189
Materials and supplies...................................... 8,837 7,776
------- -------
Total inventories........................................... $63,682 $84,331
======= =======
</TABLE>
At December 31, 1996 and 1997, crude oil and product inventories at LIFO
cost were below current cost by approximately $16.3 million and $7.8 million,
respectively.
4. PROPERTY, PLANT AND EQUIPMENT, GOODWILL, RELATED WRITE-DOWNS, AND CHANGE IN
DEPRECIATION METHOD
In 1997 BHP developed a plan to sell the Company, engaged an investment
advisor, completed an appraisal of assets, and began discussions with potential
buyers. Management determined that net book value of refinery assets had been
impaired based in part on the appraisal. The refinery property, plant and
equipment were written down to estimated fair value in May 1997, based on an
evaluation of these assets, related operating results, and in accordance with
provisions of Statement of Financial Accounting Standards (SFAS) No. 121. The
write-down, net of accumulated depreciation, amounted to $88.8 million ($54.2
million after a $34.6 million reduction in deferred income taxes). In accordance
with SFAS No. 121, no depreciation and amortization expense has been included in
the financial statements since May 1997. BHP reached an agreement in March 1998
to sell the Company, and as a result of the sale, the Company anticipates
recognizing an estimated loss of approximately $120-125 million, in addition to
the loss recognized in May 1997 (see Note 8). Substantially all of the loss is
expected to be allocated to a further reduction in the fair value of the
property, plant and equipment.
In connection with management's determination that the carrying amount of
refinery assets had become impaired, it was also determined that goodwill had no
continuing value. Therefore, the remaining net goodwill of $30,351 ($51,636, net
of accumulated amortization of $21,285) was also written off in May 1997.
Goodwill amortization expense included in statements of operations was $1,505
for the seven months ended December 31, 1996.
5. INCOME TAXES
The income tax provisions were 42% and 39% of income before income taxes
for the seven months ended December 31, 1996 and 1997, respectively. The
effective income tax rates differed from the normal 35% Federal income tax rate
because of state income taxes and the effects of permanent differences between
book and tax income, primarily the amortization of goodwill in 1996.
6. RELATED PARTY BALANCES AND TRANSACTIONS
The Company enters into transactions with BHP-affiliated companies
primarily for petroleum operations and general financing activities. Crude oil
is purchased through BHP Petroleum affiliates in the U.S., Australia and
Singapore. Crude oil transportation costs are either included in the purchase
price or paid to an affiliated BHP Transport company. Export products are sold
through BHP Petroleum affiliates.
Sales of refined products to BHP affiliates are negotiated with reference
to current published market prices. Sales include export cargoes marketed
primarily in Asia. Also, naphtha and LPG were sold to a Hawaii
F-59
<PAGE> 198
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
gas utility affiliate (the Gas Company) under term contracts. BHP sold the Gas
Company to an unrelated company effective October 31, 1997, and continues to
sell products to the Gas Company.
Domestic (Alaskan North Slope) crude oil is purchased from a BHP Petroleum
affiliate at their cost, net of their price hedging transactions. BHPPAR also
imports crude oil, primarily from Australia and Asia, under term agreements with
BHP Petroleum affiliates, and purchase prices are determined by a formula using
current published market prices.
7. COMMITMENTS AND CONTINGENCIES
The Company is party to litigation and claims in the normal course of
business. The outcome of individual matters is not predictable. However,
management believes that the ultimate resolution of all of these matters, after
considering insurance coverages, is not likely to have a material adverse effect
on the Company's combined financial statements.
Environmental
The Company's operations are subject to various Federal and state
environmental laws and regulations. The Company has received notices of
violation or potential liability from the U.S. Environmental Protection Agency
(EPA), the State of Hawaii Department of Health (HDOH) and private parties
relating to various environmental matters associated with the Company's
ownership and/or operations of its assets. There have been no significant
changes in environmental matters disclosed in the audited financial statements
for the fiscal year ended May 31, 1997.
8. SUBSEQUENT EVENT
On March 18, 1998, the Company's stockholders entered into a stock sale
agreement with Tesoro Petroleum Corporation (Tesoro), whereby Tesoro will
purchase all of the outstanding common stock of BHPPAR and BHPPSP. The sale is
expected to close by the end of May 1998, subject to regulatory review and other
customary conditions. The price to be paid at closing amounts to $275 million in
cash (including a $5 million escrow deposit). After closing, the cash price will
be increased by the amount that net working capital sold exceeds $100 million,
or reduced by the amount that net working capital is less than $100 million. In
addition, Tesoro will issue an unsecured, non-interest bearing, promissory note
for $50 million payable in five equal annual installments of $10 million each,
beginning in 2009. The note will provide for earlier payment, depending on
earnings performance of the acquired assets.
The parties will execute a separate environmental agreement at closing,
whereby the selling stockholders will indemnify Tesoro and the Company for
environmental costs arising out of conditions which exist at, or existed prior
to, closing subject to a maximum limit of $9.5 million. The environmental
indemnity will survive for a ten-year period. Certain environmental liabilities
of the Companies will be retained by BHP and are not subject to the $9.5 million
indemnity.
As a result of the sale, the Company anticipates recognizing an estimated
loss of approximately $120-125 million. This estimated loss will increase or
decrease based on results of operations and changes in noncurrent assets and
liabilities through the closing date. Substantially all of the loss is expected
to be allocated to a further reduction in the fair value of the property, plant
and equipment.
* * * * * *
F-60
<PAGE> 199
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED STATEMENTS OF OPERATIONS
(UNAUDITED)
(IN THOUSANDS)
<TABLE>
<CAPTION>
TEN MONTHS ENDED
MARCH 31,
--------------------
1997 1998
-------- --------
<S> <C> <C>
REVENUES
Sales and other revenue -- trade.......................... $763,454 $651,585
Sales and other revenue -- affiliates..................... 94,322 90,363
-------- --------
Total Revenue..................................... 857,776 741,948
-------- --------
OPERATING COSTS AND EXPENSES
Cost of sales............................................. 759,555 640,699
Operating and selling..................................... 36,807 36,796
Depreciation and amortization (Note 5).................... 24,288 --
Refinery assets write-down to fair value (Note 5)......... -- 125,049
-------- --------
Total Operating Costs and Expenses................ 820,650 802,544
-------- --------
OPERATING INCOME (LOSS)..................................... 37,126 (60,596)
General and administrative................................ (14,363) (15,787)
Interest.................................................. (8,491) (8,309)
Capitalized interest...................................... 1,130 1,168
-------- --------
INCOME (LOSS) BEFORE INCOME TAXES........................... 15,402 (83,524)
Income tax benefit (provision).............................. (6,908) 21,800
-------- --------
NET INCOME (LOSS)........................................... $ 8,494 $(61,724)
======== ========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-61
<PAGE> 200
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED BALANCE SHEETS
(UNAUDITED)
(DOLLARS IN THOUSANDS)
ASSETS
<TABLE>
<CAPTION>
AS OF MARCH 31,
--------------------
1997 1998
-------- --------
<S> <C> <C>
CURRENT ASSETS
Cash...................................................... $ 2,066 $ 2,519
Accounts receivable, net.................................. 69,655 53,245
Due from affiliates -- trade.............................. 15,193 --
Due from affiliates -- other.............................. 16,723 31,059
Inventories............................................... 79,353 71,050
Other current assets...................................... 2,969 3,919
-------- --------
Total current assets.............................. 185,959 161,792
-------- --------
PROPERTY, PLANT AND EQUIPMENT, net of accumulated
depreciation and amortization............................. 383,734 209,804
-------- --------
NON-CURRENT ASSETS
Goodwill, net of accumulated amortization (Notes 2 & 5)... 30,781 --
Other..................................................... 7,314 3,295
-------- --------
Total non-current assets.......................... 38,095 3,295
-------- --------
Total Assets...................................... $607,788 $374,891
======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES:
Cash overdraft............................................ $ 6,953 $ 5,130
Accounts payable.......................................... 32,181 11,959
Due to affiliates -- trade................................ 22,923 29,742
Capital lease obligations, current portion................ 685 1,003
Accrued liabilities....................................... 12,340 12,901
-------- --------
Total current liabilities......................... 75,082 60,735
-------- --------
NOTES PAYABLE TO AFFILIATE -- noncurrent.................... 145,000 145,000
CAPITAL LEASE OBLIGATIONS, net of current portion........... 5,350 8,433
DEFERRED INCOME TAXES....................................... 67,794 --
OTHER LIABILITIES........................................... 32,503 29,460
COMMITMENTS AND CONTINGENCIES (Note 8)
STOCKHOLDERS' EQUITY
Common stock, no par value, 1,000,500 shares authorized,
issued and outstanding................................. 8,208 8,208
Additional paid-in capital................................ 52,362 52,362
Retained earnings:
BHP Petroleum Americas Refining Inc.................... 212,325 60,762
BHP Petroleum South Pacific Inc........................ 9,164 9,931
-------- --------
Total stockholders' equity........................ 282,059 131,263
-------- --------
Total Liabilities and Stockholders' Equity........ $607,788 $374,891
======== ========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-62
<PAGE> 201
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
COMBINED STATEMENTS OF CASH FLOWS
(UNAUDITED)
(IN THOUSANDS)
<TABLE>
<CAPTION>
TEN MONTHS ENDED
MARCH 31,
--------------------
1997 1998
-------- --------
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)........................................... $ 8,494 $(61,724)
Adjustments to reconcile net income (loss) to net cash
provided by operating activities:
Refinery assets write-down to fair value.................. -- 125,049
Depreciation and amortization............................. 24,288 --
Deferred income taxes..................................... 1,780 (30,659)
Changes in:
Accounts receivable, net............................... (25,742) (5,570)
Due from affiliates, trade and other................... 1,195 962
Inventories............................................ (26,999) 12,814
Other assets........................................... 3,082 1,808
Accounts payable and accrued liabilities............... 24,036 (9,919)
Due to affiliates, trade............................... 18,336 (191)
Other liabilities...................................... 757 920
-------- --------
Net cash provided by operating activities......... 29,227 33,490
CASH FLOWS FROM INVESTING ACTIVITIES --
Additions to property plant and equipment................. (27,637) (31,411)
CASH FLOWS FROM FINANCING ACTIVITIES --
Repayment of principal on capital leases.................. (567) (980)
-------- --------
Net increase in cash........................................ 1,023 1,099
Cash, beginning of period................................... 1,043 1,420
-------- --------
Cash, end of period......................................... $ 2,066 $ 2,519
======== ========
</TABLE>
The accompanying notes are an integral part of these combined financial
statements.
F-63
<PAGE> 202
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS
(UNAUDITED)
(DOLLARS IN THOUSANDS)
1. ORGANIZATION
BHP Petroleum Americas Refining Inc. (BHPPAR), a Hawaii corporation, and
BHP Petroleum South Pacific Inc. (BHPPSP), a California corporation,
collectively referred to as "the Company," are affiliated companies and
wholly-owned indirect subsidiaries of The Broken Hill Proprietary Company
Limited (BHP), an Australian company. All capital and financing requirements of
the Company are provided for by BHP, except for capital and operating leases.
BHPPAR operates an oil refinery, product storage and distribution
facilities, and retail gasoline stations in the state of Hawaii. Crude oil is
purchased through other BHP affiliates and shipped to Hawaii by tanker. Refined
product exports usually are sold through other BHP affiliates. BHPPSP is a
petroleum products marketer in American Samoa, and operates the government-owned
product storage and distribution facilities. BHPPSP purchases most of its
refined products from BHPPAR.
The Companies were part of a consolidated group, Pacific Resources, Inc.
and Subsidiaries (PRI), purchased by BHP in March 1989. The purchase price was
allocated to assets and liabilities based on fair values at the acquisition
date. The purchase price in excess of fair values was reported as goodwill until
May 1997 when the refinery assets were written down to estimated fair value and
the unamortized goodwill was written off.
2. BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES
The Company's interim combined financial statements and notes thereto have
been prepared by management without audit. Accordingly, the accompanying
financial statements reflect all adjustments that, in the opinion of management,
are necessary for a fair presentation of results for the periods presented. Such
adjustments are of a normal recurring nature. Certain information and notes
normally included in financial statements prepared in accordance with generally
accepted accounting principles have been condensed or omitted. However,
management believes that the disclosures presented herein are adequate to make
the information not misleading.
Combined Financial Statements -- The combined financial statements include
the accounts of BHPPAR and BHPPSP. These companies are combined to present the
financial position and results of operations of BHP's downstream petroleum
refining and marketing business. The combined financial statements have been
prepared using the historical costs and results of operations of the affiliated
entities. There were no significant differences in accounting methods or their
application among the combining entities. All significant intercompany balances
and transactions between the combined entities are eliminated.
Use of Estimates and Presentation -- Preparation of the combined financial
statements, in conformity with generally accepted accounting principles,
requires management to make estimates and assumptions which affect the amounts
of assets and liabilities, and disclosure of contingencies at the date of the
financial statements, and the reported amounts of revenues and expenses during
the reporting periods. Actual results could differ from these estimates.
Financial Instruments -- The carrying amounts of financial instruments,
including cash, accounts receivable, accounts payable, and certain other current
liabilities, approximate fair value because of the short maturity of these
instruments. The carrying amounts of the Company's long-term notes payable and
other obligations approximate the Company's estimate of fair values of such
items.
Hedging Activities -- The Company periodically enters into hedging
arrangements through BHP affiliates to manage petroleum price risks and not for
speculative purposes. Gains and losses from hedging are
F-64
<PAGE> 203
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
recognized in income when the hedged transaction occurs. Historically, gains and
losses from hedging transactions have not been material.
Inventories -- Crude oil and refined products are valued at the lower of
cost or market (net realizable value). Cost is determined primarily on the
last-in, first-out (LIFO) basis. Other inventories held for sale, materials and
supplies are stated at the lower of average cost, not in excess of market.
Property, Plant and Equipment -- Property, plant and equipment is stated at
cost. Major replacements, renewals and improvements are capitalized.
Maintenance, repairs and replacements, which do not improve or extend the lives
of assets, are charged to expense. The assets of the Company are held for sale
and, in accordance with provisions of Statement of Financial Accounting
Standards No. 121, the fixed assets have been written down to fair value, and no
depreciation or amortization has been recorded since May 1997. In previous
years, depreciation and amortization, including amortization of assets under
capital leases, were computed using the straight-line method over estimated
useful lives or lease terms, if shorter. Estimated useful lives range up to 20
years for buildings and up to 25 years for plant and equipment.
Refinery Maintenance Turnaround Costs -- The costs of refinery unit
shutdown and maintenance turnaround costs are included in other assets and
amortized over the estimated period of benefit, generally one to three years,
depending on the process unit.
Goodwill -- Goodwill represents BHP's purchase price in excess of the fair
values of net BHPPAR assets acquired in March 1989, after providing noncurrent
deferred tax liabilities on the difference between the assets' fair values and
their income tax basis. Goodwill was amortized on a straight-line, 20 year rate
until the goodwill was determined to be without further value and was written
off in May 1997.
Income Taxes -- Deferred tax assets and liabilities are recognized for
future income tax effects of temporary differences between financial statement
carrying amounts and the related income tax bases of assets and liabilities.
Deferred income tax assets and liabilities measurements are based on enacted tax
rates expected to apply when the temporary differences are expected to be
settled. The effect of tax rate changes on deferred tax assets and liabilities
is recognized when rate changes are enacted.
Income taxes are computed and recorded as if each company were filing
separate tax returns, although BHPPAR and BHPPSP are included in different
federal and state consolidated income tax returns which include other BHP
companies in the affiliated groups. Current income tax liabilities or refunds
are settled with BHP through intercompany accounts.
Environmental Expenditures -- Environmental expenditures for current
operations are expensed or capitalized, as appropriate. Expenditures are
capitalized if they extend the useful lives of assets, increase capacity, or
mitigate or prevent environmental contamination. Expenditures are expensed if
they are for existing conditions caused by past operations, and if the
expenditures will not contribute to future revenue generation. Liabilities are
recorded when environmental assessments and/or remedial efforts are probable and
when costs can be estimated reasonably. Such amounts are based on the estimated
timing and extent of remedial actions required by regulatory agencies,
experience gained from other sites where assessments and remediation have been
completed, and the amount of the Company's estimated liability, considering
proportional liability and financial abilities of other responsible parties.
Adjustments to accrued liabilities are made as changes in conditions and
estimated costs become known.
Pension Plans and Other Post-Employment Benefits -- Pension costs are
accounted for in conformity with Statements of Financial Accounting Standards
No. 87 and 88. Funding is based on required contributions under the Employee
Retirement Income Security Act of 1974. Other post-employment benefits,
primarily medical insurance, are accounted for in conformity with Statement of
Financial Accounting Standards No. 106.
F-65
<PAGE> 204
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
3. SALE OF THE COMPANY TO TESORO PETROLEUM CORPORATION
On March 18, 1998, the Company's stockholders entered into a stock sale
agreement with Tesoro Petroleum Corporation (Tesoro), whereby Tesoro will
purchase all of the outstanding common stock of BHPPAR and BHPPSP. The sale is
expected to close by the end of May 1998, subject to regulatory review and other
customary conditions. The price to be paid at closing amounts to $275 million in
cash (including a $5 million escrow deposit). After closing, the cash price will
be increased by the amount that net working capital sold exceeds $100 million,
or reduced by the amount that net working capital is less than $100 million. In
addition, Tesoro will issue an unsecured, non-interest bearing, promissory note
for $50 million payable in five equal annual installments of $10 million each,
beginning in 2009. The note will provide for earlier payment, depending on
earnings performance of the acquired assets.
The parties will execute a separate environmental agreement at closing ,
whereby the selling stockholders will indemnify Tesoro and the Company for
environmental costs arising out of conditions which exist at, or existed prior
to, closing subject to a maximum limit of $9.5 million. The environmental
indemnity will survive for a ten-year period. Certain environmental liabilities
of the Companies will be retained by BHP and are not subject to the $9.5 million
indemnity.
4. INVENTORIES
Inventories at March 31 consisted of:
<TABLE>
<CAPTION>
1997 1998
------- -------
<S> <C> <C>
Crude oil and refined products.............................. $69,366 $62,519
Merchandise and packaged petroleum products................. 954 1,139
Materials and supplies...................................... 9,033 7,392
------- -------
Total inventories................................. $79,353 $71,050
======= =======
</TABLE>
At March 31, 1997 crude oil and product inventories at LIFO cost were below
current cost by approximately $4.9 million. At March 31, 1998 crude oil and
product inventories were stated at estimated net realizable value which was $7.8
million less than LIFO cost.
5. PROPERTY, PLANT AND EQUIPMENT, GOODWILL, RELATED WRITE-DOWNS, AND CHANGE IN
DEPRECIATION METHOD
In 1997 BHP developed a plan to sell the Company, engaged an investment
advisor, completed an appraisal of assets, and began discussions with potential
buyers. Management determined that net book value of refinery assets had been
impaired based in part on the appraisal. The refinery property, plant and
equipment were written down to estimated fair value in May 1997, based on an
evaluation of these assets, related operating results, and in accordance with
provisions of Statement of Financial Accounting Standards (SFAS) No. 121. The
write-down, net of accumulated depreciation, amounted to $88.8 million. As
described in Note 3, BHP reached an agreement to sell the Company to Tesoro in
March 1998. Based on the provisions of the agreement, assets were written down
an additional $125.0 million. In accordance with SFAS No. 121, no depreciation
and amortization expense has been included in the financial statements since May
1997.
In connection with management's determination that the carrying amount of
refinery assets had become impaired, it was also determined that goodwill had no
continuing value. Therefore, the remaining net goodwill of $30,351 ($51,636, net
of accumulated amortization of $21,285) was also written off in May 1997.
Goodwill amortization expense included in statements of operations was $2,150
for the ten months ended March 31, 1997.
F-66
<PAGE> 205
BHP PETROLEUM AMERICAS REFINING INC.
BHP PETROLEUM SOUTH PACIFIC INC.
NOTES TO COMBINED FINANCIAL STATEMENTS -- (CONTINUED)
6. INCOME TAXES
The income tax provision (benefit) was 45% and (26)% of income (loss)
before income taxes for the ten months ended March 31, 1997 and 1998,
respectively. The effective income tax rates differed from the normal 35%
Federal income tax rate because of state income taxes and the effects of
permanent differences between book and tax income, primarily the amortization of
goodwill in 1997. In 1998 the effective income tax benefit was reduced by a
valuation allowance of $10.6 million for all net deferred tax assets as of March
31, 1998. Management believes that it is more likely than not that the net
deferred tax assets will not be realized, in part due to the pending sale of the
Company.
7. RELATED PARTY BALANCES AND TRANSACTIONS
The Company enters into transactions with BHP-affiliated companies
primarily for petroleum operations and general financing activities. Crude oil
is purchased through BHP Petroleum affiliates in the U.S., Australia and
Singapore. Crude oil transportation costs are either included in the purchase
price or paid to an affiliated BHP Transport company. Export products are sold
through BHP Petroleum affiliates.
Sales of refined products to BHP affiliates are negotiated with reference
to current published market prices. Sales include export cargoes marketed
primarily in Asia. Also, naphtha and LPG were sold to a Hawaii gas utility
affiliate (the Gas Company) under term contracts. BHP sold the Gas Company to an
unrelated company effective October 31, 1997, and continues to sell products to
the Gas Company.
Domestic (Alaskan North Slope) crude oil is purchased from a BHP Petroleum
affiliate at their cost, net of their price hedging transactions. BHPPAR also
imports crude oil, primarily from Australia and Asia, under term agreements with
BHP Petroleum affiliates, and purchase prices are determined by a formula using
current published market prices.
8. COMMITMENTS AND CONTINGENCIES
The Company is party to litigation and claims in the normal course of
business. The outcome of individual matters is not predictable. However,
management believes that the ultimate resolution of all of these matters, after
considering insurance coverages, is not likely to have a material adverse effect
on the Company's combined financial statements.
The Company's operations are subject to various Federal and state
environmental laws and regulations. The Company has received notices of
violation or potential liability from the U.S. Environmental Protection Agency
(EPA), the State of Hawaii Department of Health (HDOH) and private parties
relating to various environmental matters associated with the Company's
ownership and/or operations of its assets. There have been no significant
changes in environmental matters disclosed in the audited financial statements
for the fiscal year ended May 31, 1997.
* * * * * *
F-67
<PAGE> 206
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and
Shareholder of Shell Anacortes Refining Company
In our opinion, the accompanying balance sheet and the related statements of
income and shareholder's equity and of cash flows present fairly, in all
material respects, the financial position of Shell Anacortes Refining Company at
December 31, 1997 and 1996, and the results of its operations and its cash flows
for the year ended December 31, 1997 and for the period from inception (January
4, 1996) through December 31, 1996, in conformity with generally accepted
accounting principles. These financial statements are the responsibility of the
Company's management; our responsibility is to express an opinion on these
financial statements based on our audits. We conducted our audits of these
statements in accordance with generally accepted auditing standards which
require that we plan and perform the audit to obtain reasonable assurance about
whether the financial statements are free of material misstatement. An audit
includes examining, on a test basis, evidence supporting the amounts and
disclosures in the financial statements, assessing the accounting principles
used and significant estimates made by management, and evaluating the overall
financial statement presentation. We believe that our audits provide a
reasonable basis for the opinion expressed above.
/s/ PRICE WATERHOUSE LLP
Price Waterhouse LLP
Houston, Texas
May 29, 1998
F-68
<PAGE> 207
SHELL ANACORTES REFINING COMPANY
STATEMENT OF INCOME
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
FOR THE PERIOD
FROM INCEPTION FOR THE THREE MONTHS ENDED
(JANUARY 4, 1996) YEAR ENDED MARCH 31,
THROUGH DECEMBER 31, --------------------
DECEMBER 31, 1996 1997 1997 1998
----------------- ------------ -------- --------
(UNAUDITED)
<S> <C> <C> <C> <C>
REVENUES:
Sales
Third Parties......................... $296,168 $ 544,295 $130,553 $127,513
Related Parties....................... 525,120 545,623 160,662 73,918
Interest and other income................ 732 52 120 30
-------- ---------- -------- --------
Total Revenues........................... 822,020 1,089,970 291,335 201,461
-------- ---------- -------- --------
COSTS AND EXPENSES:
Purchases of raw materials
Third Parties......................... 542,949 888,057 260,887 161,142
Related Parties....................... 153,848 61,557 11,442 19,475
Other operating expenses................. 58,352 68,750 3,000 11,025
Depreciation and amortization............ 8,607 12,715 3,101 3,703
Operating taxes.......................... 11,458 18,584 5,043 3,752
Selling, general and administrative...... 7,547 14,277 3,042 2,512
Research and development................. 1,083 1,137 357 291
Interest expense on advances............. 9 252 37 10
-------- ---------- -------- --------
783,853 1,065,329 286,909 201,910
-------- ---------- -------- --------
Income (loss) before income taxes........ 38,167 24,641 4,426 (449)
Income tax............................... 13,444 8,902 1,636 (80)
-------- ---------- -------- --------
Net income (loss)........................ $ 24,723 $ 15,739 $ 2,790 $ (369)
======== ========== ======== ========
</TABLE>
The accompanying notes are an integral part of this statement.
F-69
<PAGE> 208
SHELL ANACORTES REFINING COMPANY
BALANCE SHEET
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
AS OF AS OF AS OF
DECEMBER 31, DECEMBER 31, MARCH 31,
1996 1997 1998
------------ ------------ ------------
(UNAUDITED)
<S> <C> <C> <C>
ASSETS
Current Assets:
Cash and cash equivalents............................. $ 25 $ 25 $ 25
Advances to Shell Oil Company......................... -- 6,470 --
Owing by related parties.............................. 45,991 17,512 11,313
Other receivables..................................... 1,486 363 1,287
Inventories of product and crude...................... 4,987 25,321 37,398
Inventories of materials and supplies................. 3,676 3,774 3,907
Other current assets.................................. 1,777 1,789 4,349
-------- -------- --------
Total Current Assets.......................... 57,942 55,254 58,279
Property, Plant and Equipment at cost, less
accumulated depreciation and amortization.......... 188,876 184,424 184,641
Other Noncurrent Assets............................... 7,524 8,093 8,774
-------- -------- --------
TOTAL ASSETS.................................. $254,342 $247,771 $251,694
======== ======== ========
LIABILITIES AND SHAREHOLDER'S EQUITY
Current Liabilities:
Accounts payable...................................... $ 5,601 $ 5,030 $ 6,266
Advances from Shell Oil Company....................... 5,656 -- --
Income, operating, and consumer taxes................. 4,557 1,290 952
Owing to related parties.............................. 637 380 3,553
Other current liabilities............................. 3,855 3,753 3,881
-------- -------- --------
Total Current Liabilities..................... 20,306 10,453 14,652
Long-Term Liabilities................................. 13,240 14,149 14,412
Deferred Income Taxes................................. 24,059 25,693 25,523
-------- -------- --------
Total Liabilities............................. 57,605 50,295 54,587
-------- -------- --------
Shareholder's Equity:
Common Stock:
3,000 shares authorized, issued and outstanding at
$1.00 par value.................................. 3 3 3
Additional Paid in Capital......................... 181,011 181,011 181,011
Retained Earnings.................................. 15,723 16,462 16,093
-------- -------- --------
Total Shareholder's Equity.................... 196,737 197,476 197,107
-------- -------- --------
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY.... $254,342 $247,771 $251,694
======== ======== ========
</TABLE>
The accompanying notes are an integral part of this statement.
F-70
<PAGE> 209
SHELL ANACORTES REFINING COMPANY
STATEMENT OF SHAREHOLDER'S EQUITY
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
ADDITIONAL
COMMON PAID-IN RETAINED
STOCK CAPITAL EARNINGS TOTAL
------ ---------- -------- --------
<S> <C> <C> <C> <C>
Initial Capital Contribution........................ $-- $ 1 $ -- $ 1
Contribution of Anacortes refinery net assets....... 3 181,010 -- 181,013
Net income.......................................... -- -- 24,723 24,723
Dividends........................................... -- -- (9,000) (9,000)
--- -------- -------- --------
Balance at December 31, 1996........................ 3 181,011 15,723 196,737
Net income.......................................... -- -- 15,739 15,739
Dividends........................................... -- -- (15,000) (15,000)
--- -------- -------- --------
Balance at December 31, 1997........................ 3 181,011 16,462 197,476
Net income (loss) (unaudited)....................... -- -- (369) (369)
--- -------- -------- --------
Balance at March 31, 1998 (unaudited)............... $ 3 $181,011 $ 16,093 $197,107
=== ======== ======== ========
</TABLE>
The accompanying notes are an integral part of this statement.
F-71
<PAGE> 210
SHELL ANACORTES REFINING COMPANY
STATEMENT OF CASH FLOWS
(THOUSANDS OF DOLLARS)
<TABLE>
<CAPTION>
FROM INCEPTION THREE MONTHS ENDED
(JANUARY 4, 1996) FOR THE MARCH 31,
THROUGH YEAR ENDED --------------------
DECEMBER 31, 1996 DECEMBER 31, 1997 1997 1998
----------------- ----------------- -------- --------
(UNAUDITED)
<S> <C> <C> <C> <C>
Cash Flow Provided by Operating Activities:
Net income (loss).............................. $ 24,723 $ 15,739 $ 2,790 $ (369)
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation and amortization.............. 8,607 12,715 3,101 3,703
Deferred income taxes...................... 2,620 1,634 1,019 (170)
(Increases) decreases in working capital:
Owing by related parties................ (33,525) 28,479 45,990 6,199
Other receivables....................... (1,419) 1,123 (22,169) (924)
Inventories of product and crude........ 1,013 (20,334) (19,170) (12,077)
Inventories of materials and supplies... 1,252 (98) (48) (133)
Other current assets.................... (447) (12) 88 (2,560)
Accounts payable........................ 2,240 (571) (1,896) 1,236
Income, operating and consumer taxes.... 3,642 (3,267) 1,462 (338)
Owing to related parties................ (1,750) (257) 6,572 3,173
Other current liabilities............... 122 (102) (594) 128
Other noncurrent items..................... 1,450 340 141 (418)
-------- -------- -------- --------
Net Cash Provided by Operating Activities...... 8,528 35,389 17,286 (2,550)
-------- -------- -------- --------
Cash Flow Used for Investing Activities:
Capital expenditures........................... (4,892) (8,157) (2,625) (3,456)
Proceeds from property sales and salvage, net
of removal costs............................. (293) (106) 20 (464)
Advances to Shell Oil Company.................. -- (6,470) (5,275) 6,470
-------- -------- -------- --------
Net Cash Used for Investing Activities......... (5,185) (14,733) (7,880) 2,550
-------- -------- -------- --------
Cash Flow Used for Financing Activities:
Proceeds from issuance of common stock......... 1 -- -- --
Dividends to shareholder....................... (9,000) (15,000) (3,750) --
Advances from Shell Oil Company................ 5,656 (5,656) (5,656) --
-------- -------- -------- --------
Net Cash Used for Financing Activities......... (3,343) (20,656) (9,406) --
-------- -------- -------- --------
Net increase in cash and cash equivalents........ $ -- $ -- $ -- $ --
======== ======== ======== ========
Cash and cash equivalents
Balance at Beginning of period................. $ 25 $ 25 $ 25 $ 25
Increase in cash and cash equivalents...... -- -- -- --
-------- -------- -------- --------
Balance at End of period....................... $ 25 $ 25 $ 25 $ 25
======== ======== ======== ========
Interest Paid.................................... $ 9 $ 252 $ 37 $ 9
======== ======== ======== ========
Income taxes paid................................ $ 28,355 $ 7,700 $ -- $ 1,000
======== ======== ======== ========
</TABLE>
The accompanying notes are an integral part of this statement.
F-72
<PAGE> 211
SHELL ANACORTES REFINING COMPANY
NOTES TO FINANCIAL STATEMENTS
NOTE 1 -- ORGANIZATION
Shell Anacortes Refining Company ("the Company") was incorporated in the
state of Delaware on January 4, 1996. The total number of authorized shares for
the Company is 3,000 shares of common stock with a par value of $1 per share. On
April 1, 1996, Shell Oil Products Company ("SOPC"), a subsidiary of Shell Oil
Company ("Shell"), acquired 100 shares of common stock of the Company for
$1,000. On April 30, 1996, through a series of transactions amongst Shell
subsidiaries, the 100 shares of the Company's stock, which were previously owned
by SOPC, were transferred to Shell Refining Holdings Company ("SRHC") in
exchange for their stock.
On May 1, 1996, a series of transactions were executed amongst Shell and
certain subsidiaries of Shell which culminated in SRHC contributing the assets
and property described in the Subscription Agreement as Anacortes Refinery
Assets, comprised of property, plant and equipment, crude and product inventory,
store stock, catalysts and deferred taxes on property, plant and equipment, to
the Company in exchange for 2,900 shares of the Company's stock. Prior to May 1,
1996, the Anacortes Refinery Assets were owned by Shell. Therefore, refinery
operations for the Company effectively began on May 1, 1996 upon contribution of
the assets to the Company. The Company recorded the contributed assets at the
predecessor's book value of approximately $181,013 thousand as the assets were
contributed and ultimately held by entities under control.
On May 1, 1996, simultaneously with the contribution of the Anacortes
Refinery Assets, the Company assumed certain Shell net liabilities, as follows,
in exchange for an equal amount of cash to settle these net liabilities (in
thousands):
<TABLE>
<S> <C>
Net Working Capital Deficits................................ $ 7,066
Deferred Tax Assets......................................... (497)
Prepaid Qualified Pension Plan.............................. (7,000)
Unqualified Pension Plan Liabilities........................ 500
Other Postretirement Employee Benefits Liabilities.......... 11,900
Deferred Tax on Postretirement Liabilities.................. (1,890)
-------
Cash Received............................................... $10,079
=======
</TABLE>
The cash payment was accounted for as a component of the Revolver (See Note
3).
NOTE 2 -- SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Uses of Estimates -- The preparation of financial statements in conformity
with generally accepted accounting principles requires management to make
estimates and assumptions that affect the amounts reported in the financial
statements and accompanying notes. Actual results could differ from those
estimates.
Cash Equivalents -- Cash equivalents consist of all highly liquid
investments that are readily convertible to cash and have a maturity of three
months or less at date of acquisition.
Inventories -- Inventories of crude oil and products are valued at the
lower of cost, predominantly on a last-in, first-out (LIFO) basis, or market,
and include certain costs directly related to the production process. Materials
and supplies are carried at average cost or less.
Depreciation and Amortization -- Properties, plant and equipment are
depreciated on a straight-line basis over their estimated useful lives which
range between four and twenty years. Gains and losses are not recognized for
normal retirements of properties, plant and equipment subject to composite group
amortization or depreciation. Gains or losses from abnormal retirements or sales
are recognized currently in income. Expenditures for maintenance and repairs are
expensed as incurred.
F-73
<PAGE> 212
SHELL ANACORTES REFINING COMPANY
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
Income Taxes -- The Company follows Statement of Financial Accounting
Standards ("SFAS") No. 109, "Accounting for Income Taxes". SFAS No. 109
prescribes an asset and liability approach in accounting for income taxes. It
requires that deferred tax assets and liabilities be determined using enacted
tax laws for the estimated future tax effects attributable to temporary
differences and carryforwards; the effects of future tax laws or rates are not
anticipated. Under this method, future financial results will be impacted by the
effect of future changes in income tax rates on cumulative deferred income tax
balances.
Fair Value of Financial Instruments -- The reported amounts of financial
instruments such as cash equivalents, advances to Shell Oil Company and owing by
related parties, approximate fair value because of their short maturities.
Concentration of risk -- All of the Company's trade receivables are from
Shell. Although collection of these receivables could be influenced by economic
factors affecting the petroleum industry, the risk of significant loss is
considered remote.
Impairment of Long-Lived Assets -- Statement of Financial Accounting
Standards ("SFAS") No. 121, "Accounting for the Impairment of Long-Lived Assets
and for Long-Lived Assets to be Disposed of" requires that long-lived assets and
certain identifiable intangibles to be held and used be reviewed for impairment
whenever events or changes in circumstances indicate that the carrying amount of
affected assets may not be recoverable. Long-lived assets were tested for
impairment by comparing carrying amounts with estimated future cash flows
expected from use of the assets and from their disposition. Estimates of future
cash flows were developed utilizing internal estimates of future costs, product
prices, capital costs and salvage values. At December 31, 1996 and December 31,
1997, no impairment write-down of reported balances was necessary.
Interim Financial Data -- The interim financial data for the three months
ended March 31, 1998 and March 31, 1997 is unaudited; however, in the opinion of
the Company, the interim data includes all adjustments, consisting only of
normal recurring adjustments, necessary for a fair statement of the results for
the interim period.
NOTE 3 -- TRANSACTIONS WITH RELATED PARTIES
The Company has entered into transactions with related parties including
Shell and certain of its subsidiaries. Such transactions were in the ordinary
course of business and include the purchase, sale and transportation of crude
oil and refined products, as well as charges for certain general, administrative
and other functions performed by Shell and its affiliates for the Company. The
aggregate amounts of related party transactions during 1997 and 1996 were (in
thousands):
<TABLE>
<CAPTION>
FOR THE PERIOD
FROM INCEPTION
(JANUARY 4, 1996)
THROUGH
1997 DECEMBER 31, 1996
-------- -----------------
<S> <C> <C>
Sales and other operating revenue......................... $545,623 $525,120
Purchases and transportation.............................. 61,557 153,848
Selling, general, and administrative...................... 12,952 6,553
Research and development.................................. 1,137 1,083
Interest income on Revolver............................... 35 732
Interest expense on Revolver.............................. 252 9
</TABLE>
Purchases, Sales and Receivables
Under various agreements between Shell and the Company, Shell arranges on
behalf of the Company feedstock purchases in the Company's name from third
parties and refined product sales in the Company's name to third parties. For
feedstock purchases, Shell remits payments to the suppliers and charges the
F-74
<PAGE> 213
SHELL ANACORTES REFINING COMPANY
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
Company for the cost via intercompany accounts. Pursuant to an agreement with
Shell for sales to third parties, the Company records an intercompany receivable
from Shell and Shell collects the payments from the customers on behalf of the
Company and credits the Company through the intercompany account. As a result of
this agreement, the Company has sales and purchases with third parties yet cash
on these transactions is settled via the Company's owing by/to related parties
account with Shell. Since the legal right of offset exists with Shell, trade
receivables and trade payables are reflected as a net amount within the owing
by/to related parties balance. The Company also has entered into transactions
with related parties for the purchase of feedstocks and the sale of refined
products. The related trade payables and trade receivables are also included in
the owing by/to related parties balance.
At December 31, 1997 and 1996, trade receivables and trade payables,
including the reconciliation to owing by related were as follows (in thousands):
<TABLE>
<CAPTION>
AS OF AS OF
DECEMBER 31, DECEMBER 31,
1997 1996
------------ ------------
<S> <C> <C>
Trade receivables........................................... $86,502 $111,367
Trade payables.............................................. 67,914 83,708
------- --------
Net owing by related parties balance for trade receivables
and payables.............................................. 18,588 27,659
Receivable for overpayment of taxes (see below)............. -- 17,872
Other owing by related parties, net......................... (1,076) 460
------- --------
Owing by related parties.................................... $17,512 $ 45,991
======= ========
</TABLE>
Advances with Shell
The Company is party to a Revolving Credit and Cash Management Agreement
(the "Revolver") with Shell. Under the Agreement, the Company will advance its
excess cash (including net cash resulting from the proceeds of the refining
business) to Shell, and Shell will pay the Company interest on such advances at
a rate equal to the prime rate established from time to time by The Chase
Manhattan Bank (N.A.), less one percent. In addition, under the Agreement, Shell
has irrevocably committed to make a line of credit available to the Company in
an aggregate principal amount not exceeding $40 million. The Company may draw on
this line of credit on demand. Funds advanced by Shell to the Company under this
line of credit will bear interest at the prime rate established from time to
time by The Chase Manhattan Bank (N.A.).
The funds maintained in the Revolver are liquid and available for use at
the Company's discretion. Funds advanced to Shell under the Revolver as of
December 31, 1997 amounted to $6.5 million and the interest rate on the amount
outstanding at December 31, 1997 was 7.5%. As of December 31, 1996, funds
advanced to the Company by Shell amounted to $5.7 million and the interest rate
on the amount outstanding at December 31, 1996 was 8.25%. Under the Revolver
there were amounts advanced to Shell and amounts due to Shell at various times
throughout the period from the date of commencement of the Revolver (April 1,
1996) to December 31, 1997. Interest income earned on the funds advanced to
Shell for the year ended December 31, 1997 and the period from inception
(January 4, 1996) to December 31, 1996 amounted to $35 thousand and $732
thousand, respectively. Interest expense incurred on the funds advanced from
Shell for the year ended December 31, 1997 and the period from inception
(January 4, 1996) to December 31, 1996 amounted to $252 thousand and $9
thousand, respectively.
Cost Sharing and other charges
Under the Cost Sharing Agreement between Shell and the Company, research,
development, and technology service costs related to the refining of crude oil
and other raw materials are allocated to the
F-75
<PAGE> 214
SHELL ANACORTES REFINING COMPANY
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
Company based upon a percentage equal to the Company's equivalent distillation
capacity as compared to the combined capacity for all refineries participating
under the agreement. The Company is required under the agreement to pay Shell
its share of estimated research, development, and technology service costs on a
monthly basis. The Company is also charged for certain overhead administrative
expenses at rates which have been agreed upon by the Company and Shell.
Receivable for overpayment of taxes
The Company files a separate tax return; however, for the period from
inception (January 4, 1996) through December 31, 1996, the Company paid their
estimated tax liability to SRHC which then remitted the taxes for itself and
certain of its subsidiaries, including the Company, to the Internal Revenue
Service. The amount submitted by the Company exceeded their tax liability by
approximately $17 million due to estimates of the tax liability differing from
actual results. The amount due for the overpayment is recorded in the owing by
related parties balance.
NOTE 4 -- INVENTORIES OF CRUDE OILS AND REFINED PRODUCTS
Inventories are carried on a LIFO basis which was lower than current cost
by $1.6 million at December 31, 1997 and $12.3 million at December 31, 1996.
A portion of Shell's inventory was held on consignment by the Company. The
title to and ownership of such inventory is intended to remain with Shell until
purchased by the refining company in accordance with the Feedstock Consignment
Agreement. For the year ended December 31, 1997 and the period from inception
(January 4, 1996) through December 31, 1996, $13,395 thousand and $14,690
thousand, respectively, of crude and refined products were purchased from
consignment. As of December 31, 1997, all the consigned crude inventory had been
purchased by the Company with some product inventory remaining on consignment.
During the period from May 1, 1996, the date of contribution of the
Anacortes Refinery Assets, to December 31, 1996 inventory quantities were
reduced. This reduction resulted in a liquidation of LIFO inventory quantities
carried at lower costs prevailing in prior years, as the inventory was
contributed at book value, as compared with the 1996 purchases for the period
from May 1, 1996 to December 31, 1996, the effect of which decreased operating
expenses by approximately $2,825 thousand.
NOTE 5 -- PROPERTY, PLANT AND EQUIPMENT
Investments in property, plant and equipment as of December 31, 1997 and
1996, respectively, are reported at historical cost as follows (in thousands):
<TABLE>
<CAPTION>
1997 1996
------------------------------ ------------------------------
COST RESERVE* NET COST RESERVE* NET
-------- -------- -------- -------- -------- --------
<S> <C> <C> <C> <C> <C> <C>
Land.................. $ 2,808 $ 2,808 $ 2,808 $ 2,808
Manufacturing
assets.............. 342,844 $161,228 181,616 334,693 $148,625 186,068
-------- -------- -------- -------- -------- --------
Total....... $345,652 $161,228 $184,424 $337,501 $148,625 $188,876
======== ======== ======== ======== ======== ========
</TABLE>
* Accumulated depreciation and amortization.
F-76
<PAGE> 215
SHELL ANACORTES REFINING COMPANY
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
NOTE 6 -- TAXES
Operating and income taxes incurred by the Company in 1997 and 1996 were as
follows (in thousands):
<TABLE>
<CAPTION>
FOR THE PERIOD
FROM INCEPTION
(JANUARY 4, 1996)
THROUGH
DECEMBER 31,
1997 1996
------- -----------------
<S> <C> <C>
Operating Taxes
- ------------------------------------------------------------
Hazardous substance....................................... $ 8,092 $ 3,978
Business and occupation................................... 5,745 4,980
Real and personal property................................ 2,089 1,192
Payroll................................................... 1,377 657
Other..................................................... 1,281 651
------- -------
$18,584 $11,458
======= =======
Federal and Other Incomes Taxes
- ------------------------------------------------------------
Current:
Federal................................................ $ 6,758 $10,484
State.................................................. 510 340
Deferred:
Federal................................................ 1,634 2,620
------- -------
$ 8,902 $13,444
======= =======
</TABLE>
Total income tax expense for 1997 and 1996 was equivalent to an effective
tax rate of 36% and 35%, respectively. Reconciliation to the expected tax at the
U.S. statutory rate of 35% is as follows (in thousands):
<TABLE>
<CAPTION>
FOR THE PERIOD
FROM INCEPTION
(JANUARY 4, 1996)
THROUGH
DECEMBER 31,
1997 1996
------ -----------------
<S> <C> <C>
Expected tax at statutory rate.............................. $8,624 $13,358
State tax................................................... 332 221
Other....................................................... (54) (135)
------ -------
$8,902 $13,444
====== =======
</TABLE>
F-77
<PAGE> 216
SHELL ANACORTES REFINING COMPANY
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
Deferred income taxes are provided for the temporary differences between
the tax basis of the Company's assets and liabilities and the amounts reported
in the financial statements. Significant components of deferred tax liabilities
and assets as of December 31, 1997 and December 31, 1996 are as follows (in
millions):
<TABLE>
<CAPTION>
1997 1996
---- ----
<S> <C> <C>
Deferred tax liabilities:
- ------------------------------------------------------------
Depreciation of properties, plant, and equipment.......... $30 $27
Other..................................................... 2 1
--- ---
Total deferred tax liabilities.................... 32 28
--- ---
Deferred tax assets:
- ------------------------------------------------------------
Other postretirement liabilities.......................... 4 4
Other..................................................... 2 --
--- ---
Total deferred tax assets......................... 6 4
--- ---
Net deferred tax liabilities...................... $26 $24
=== ===
</TABLE>
The Company has assessed the need for establishing a valuation allowance
for its deferred tax assets and has determined that such an allowance is
unnecessary.
NOTE 7 -- POSTRETIREMENT BENEFITS
The employees associated with fuels operations of the refinery became
employees of the refinery subsidiary on April 1, 1996. In participation with
Shell, the Company currently provides health care benefits for retired employees
and their dependents. Eligibility for such benefits requires retirement from the
Company with entitlement to an immediate pension generally upon the earlier of
the attainment of age 50, when such age plus years of service equals 80, or the
attainment of age 65. Other postretirement benefits provided to the employees
include life insurance benefits. These life insurance benefits are primarily
funded by employees; as a result, the cost of such benefits to the Company is
not material.
The health care benefits for retired employees and their dependents are
provided by Shell's unfunded defined benefit plans. The benefit is defined as
the Company's contributions to such plans. Annually, retirees are advised of the
amount of the Company's monthly contribution to the plans for the following year
and the monthly amount such retirees must pay for the particular coverage
desired. Retiree health care costs allocated from Shell amounted to $503
thousand in 1997 and $364 thousand in 1996. Other long-term liabilities include
$11.9 million in connection with retiree health care cost allocations as of both
December 31, 1997 and 1996.
As of May 1, 1996, the pre-existing liabilities of the refinery
subsidiaries for post-retirement benefits of $11.9 million were conveyed to the
Company in addition to an equal amount of cash to settle the net liabilities,
based on actuarial data.
F-78
<PAGE> 217
SHELL ANACORTES REFINING COMPANY
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
NOTE 8 -- PENSION PLAN AND PROVIDENT FUND
The Company participates with Shell in the Shell Pension Plan (Plan), the
Benefit Restoration Plan, the Senior Staff Plan, and the Shell Provident Fund.
The Plan covers substantially all of the Company's employees. Benefits are based
on years of service and the employee's average final compensation. The prepaid
cost (accrued liability) conveyed to the Company on May 1, 1996 in addition to
an equal amount of cash to settle the net liability, based on actuarial data was
as follows (in millions):
<TABLE>
<CAPTION>
MAY 1,
1996
------
<S> <C>
Qualified Pension Plan
Employees................................................. $ 3
Pensioners and deferred vested............................ 4
----
$ 7
====
Non-qualified Pension Plan
Employees................................................. $(.3)
Pensioners and deferred vested............................ (.2)
----
$(.5)
====
</TABLE>
There were no contributions to the Shell Pension Trust since May 1, 1996
due to the full-funding limitation of the applicable law. The Benefits
Restoration Plan generally provides for payments of amounts in excess of limits
imposed by federal tax law on benefit payments under the Shell Pension Plan. The
Senior Staff Plan provides for defined monthly supplemental pension payments to
members of the senior staff (consisting of certain officers and other high
ranking employees). Both of these plans are unfunded. The Shell Provident Fund
covers employees of the Company after stated periods of service, and provides
for contributions by the employing company based on a stated percentage of the
employees' salaries and wages. Employees may also contribute amounts up to a
stated percentage. The Company's portion of the total cost of the Shell
Provident Plan and the Shell Pension Plan was $1,306 thousand and $523 thousand,
respectively, in 1997, and was $774 thousand and $540 thousand, respectively, in
1996.
NOTE 9 -- CONTINGENCIES AND OTHER MATTERS
The Company and related Shell subsidiaries are named defendants in certain
lawsuits and named parties in certain governmental proceedings arising in the
ordinary course of business. While the outcome of such contingencies, lawsuits
or other proceedings against the Company cannot be predicted with certainty,
management expects that such liability, to the extent not provided for through
insurance or otherwise, will not have material adverse effect on the financial
statements of the Company.
In connection with the commencement of operations of the Company, Shell
agreed to retain liability for, and indemnify the Company for all other
liabilities and costs arising as the result of governmental or private claims,
suits or enforcement actions, either threatened or asserted prior to May 1, 1996
or arising out of acts or incidents occurring prior to May 1, 1996, except for
environmental claims, suits or actions. As to environmental claims, suits or
actions, either private or governmental, and all other environmental costs and
expenses, Shell has agreed to indemnify the Company for all liabilities and
costs (including those for claims, suits or actions) in any year which exceed
the budgeted environmental expenditures for such year.
F-79
<PAGE> 218
SHELL ANACORTES REFINING COMPANY
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
NOTE 10 -- SUBSEQUENT EVENTS
On January 15, 1998, Shell Oil and Texaco Inc. ("Texaco") reached an
agreement on the formation and operational start up of Equilon Enterprises LLC
("Equilon"). Equilon is a joint venture which combines major elements of both
companies' western and midwestern United States refining and marketing
businesses and both companies' nationwide trading, transportation and lubricants
businesses.
The Company will be sold as part of a settlement agreement with the Federal
Trade Commission involving the joint venture with Texaco. Beginning in December
1997, the Company must be held separate from all other operations within Shell
and Texaco. On May 1, 1998, Shell Oil Company entered into an agreement to sell
the stock of the Company to Tesoro Petroleum Corporation ("Tesoro"). Tesoro will
acquire the Company for $237 million plus an additional payment for net working
capital at the time of closing. The Federal Trade Commission and the states of
Oregon and Washington will have final approval of the transaction and Tesoro as
the buyer.
Also as part of Federal Trade Commission agreement, effective January 1,
1998, the Company acquired all the third parties contracts in the state of
Oregon previously held by Shell and purchased the associated inventory in the
state of Oregon.
F-80
<PAGE> 219
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ALL TENDERED OLD NOTES, EXECUTED LETTERS OF TRANSMITTAL AND OTHER RELATED
DOCUMENTS SHOULD BE DIRECTED TO THE EXCHANGE AGENT. QUESTIONS AND REQUESTS FOR
ASSISTANCE AND REQUESTS FOR ADDITIONAL COPIES OF THE PROSPECTUS, THE LETTER OF
TRANSMITTAL AND OTHER RELATED DOCUMENTS SHOULD BE ADDRESSED TO THE EXCHANGE
AGENT AS FOLLOWS:
By Registered, Certified, or
Overnight Mail or Courier:
U.S. BANK TRUST N.A.
Attn: Specialized Finance
SPFT0414
180 East Fifth Street
St. Paul, MN 55101
By Hand:
U.S. BANK TRUST N.A.
4th Floor Bond Drop Window
180 East Fifth Street
St. Paul, MN 55101
By Facsimile:
(For Eligible Institutions Only):
(651) 244-1537
By First Class Mail:
U.S. BANK TRUST N.A.
P.O. Box 64485
St. Paul, MN 55164-9549
To Confirm by Telephone
or for Information, Call:
(651) 244-1197
(Originals of all documents submitted by facsimile should be sent promptly by
hand, overnight delivery, or registered or certified mail.)
---------------------
NO DEALER, SALESMAN OR OTHER PERSON HAS BEEN AUTHORIZED TO GIVE ANY
INFORMATION OR TO MAKE ANY REPRESENTATIONS NOT CONTAINED IN THIS PROSPECTUS. IF
GIVEN OR MADE, SUCH INFORMATION OR REPRESENTATIONS MUST NOT BE RELIED UPON AS
HAVING BEEN AUTHORIZED BY THE COMPANY, THE INITIAL PURCHASERS OR ANY OF THEIR
RESPECTIVE AFFILIATES. THIS PROSPECTUS DOES NOT CONSTITUTE AN OFFER TO SELL, OR
A SOLICITATION TO BUY, THE NOTES IN ANY JURISDICTION WHERE SUCH AN OFFER OR
SOLICITATION WOULD BE UNLAWFUL. NEITHER THE DELIVERY OF THIS PROSPECTUS NOR ANY
SALE MADE HEREUNDER SHALL, UNDER ANY CIRCUMSTANCES, CREATE AN IMPLICATION THAT
THERE HAS NOT BEEN ANY CHANGE IN THE FACTS SET FORTH IN THIS PROSPECTUS OR IN
THE AFFAIRS OF THE COMPANY SINCE THE DATE HEREOF.
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$300,000,000
EXCHANGE OFFER
TESORO PETROLEUM
CORPORATION
9% SENIOR SUBORDINATED NOTES
DUE 2008, SERIES B
------------------------
PROSPECTUS
------------------------
TABLE OF CONTENTS
<TABLE>
<CAPTION>
<S> <C>
Prospectus Summary.......................... 1
Forward-Looking Statements.................. 18
Risk Factors................................ 19
The Exchange Offer.......................... 29
Use of Proceeds............................. 38
Capitalization.............................. 39
Pro Forma Financial Statements.............. 40
Selected Historical Financial Data.......... 46
Management's Discussion and Analysis of
Financial Condition and Results of
Operations................................ 48
Business.................................... 66
Management.................................. 86
Description of Other Indebtedness........... 89
Description of the Notes.................... 92
Description of Capital Stock................ 128
Certain Federal Income Tax Considerations... 130
Plan of Distribution........................ 133
Legal Matters............................... 133
Experts..................................... 133
Available Information....................... 134
Incorporation of Certain Documents by
Reference................................. 134
Index to Financial Statements............... F-1
</TABLE>
August 7, 1998
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