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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
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FORM 10-K
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1998
or
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ____________ to ____________
COMMISSION FILE NUMBER 1-1204
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AMERADA HESS CORPORATION
(Exact name of Registrant as specified in its charter)
DELAWARE
(State or other jurisdiction of incorporation or organization)
13-4921002
(I.R.S. Employer Identification Number)
<TABLE>
<S> <C>
1185 AVENUE OF THE AMERICAS, NEW YORK, N.Y. 10036
(Address of principal executive offices) (Zip Code)
</TABLE>
(Registrant's telephone number, including area code, is (212) 997-8500)
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SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
<TABLE>
<CAPTION>
NAME OF EACH EXCHANGE
TITLE OF EACH CLASS ON WHICH REGISTERED
------------------- ---------------------
<S> <C>
Common Stock (par value $1.00) New York Stock Exchange
Toronto Stock Exchange
</TABLE>
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT: None
Indicate by check mark whether the Registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
Registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes X No __
Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the
best of Registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. [ ]
The aggregate market value of voting stock held by non-affiliates of the
Registrant amounted to $3,480,000,000 as of February 28, 1999.
At February 28, 1999, 90,366,705 shares of Common Stock were outstanding.
Certain items in Parts I and II incorporate information by reference from
the 1998 Annual Report to Stockholders and Part III is incorporated by reference
from the Proxy Statement for the annual meeting of stockholders to be held on
May 5, 1999.
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PART I
ITEM 1. BUSINESS
Amerada Hess Corporation (the "Registrant") was incorporated in 1920 in the
State of Delaware. The Registrant and its subsidiaries (collectively referred to
herein as the "Corporation") engage in the exploration for and the production,
purchase, transportation and sale of crude oil and natural gas. The Corporation
also manufactures, purchases, transports and markets refined petroleum and other
energy products.
EXPLORATION AND PRODUCTION
The Corporation's exploration and production activities are located
primarily in the United States, United Kingdom, Norway and Gabon. The
Corporation also conducts exploration and/or production activities in
Azerbaijan, Brazil, Denmark, Indonesia, Thailand and certain other countries. Of
the Company's proved reserves (on a barrel of oil equivalent basis), 29% are
located in the United States, 58% are located in the United Kingdom, Norwegian
and Danish sectors of the North Sea and the remainder are located in Azerbaijan,
Gabon, Indonesia and Thailand. Worldwide crude oil and natural gas liquids
production amounted to 205,989 barrels per day in 1998 compared with 218,572
barrels per day in 1997. Worldwide natural gas production was 576,477 Mcf per
day in 1998 compared with 569,254 Mcf per day in 1997.
At December 31, 1998, the Corporation had 695 million barrels of proved
crude oil and natural gas liquids reserves compared with 595 million barrels at
the end of 1997. Proved natural gas reserves were 2,055 million Mcf at December
31, 1998 compared with 1,935 million Mcf at December 31, 1997. The Corporation
has a number of oil and gas developments underway in the United States, United
Kingdom, Denmark and in other international areas. It also has an inventory of
domestic and foreign drillable prospects.
UNITED STATES. The Corporation operates principally offshore in the Gulf
of Mexico and onshore in the states of Texas, Louisiana and North Dakota. During
1998, 22% of the Corporation's crude oil and natural gas liquids production and
51% of its natural gas production were from United States operations.
The table below sets forth the Corporation's average daily net production
by area in the United States:
<TABLE>
<CAPTION>
1998 1997
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<S> <C> <C>
CRUDE OIL, INCLUDING CONDENSATE AND
NATURAL GAS LIQUIDS (BARRELS PER DAY)
Texas..................................................... 15,803 16,136
North Dakota.............................................. 12,958 12,077
Gulf of Mexico............................................ 11,041 10,295
Louisiana................................................. 1,588 1,700
Other..................................................... 3,530 3,742
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Total............................................. 44,920 43,950
======= =======
NATURAL GAS (MCF PER DAY)
Gulf of Mexico............................................ 116,392 104,803
North Dakota.............................................. 58,476 59,576
Louisiana................................................. 56,627 43,668
Texas..................................................... 26,023 52,402
California*............................................... 18,320 17,779
New Mexico................................................ 12,442 17,467
Mississippi............................................... 5,569 14,972
Other..................................................... -- 1,248
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Total............................................. 293,849 311,915
======= =======
</TABLE>
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* Properties sold in January 1999.
UNITED KINGDOM. The Corporation's activities in the United Kingdom are
conducted by its wholly-owned subsidiary, Amerada Hess Limited. During 1998, 56%
of the Corporation's crude oil and natural gas liquids production and 44% of its
natural gas production were from United Kingdom operations.
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The table below sets forth the Corporation's average daily net production
in the United Kingdom by field and the Corporation's interest in each at
December 31, 1998:
<TABLE>
<CAPTION>
INTEREST 1998 1997
PRODUCING FIELD -------- ---- ----
<S> <C> <C> <C>
CRUDE OIL, INCLUDING CONDENSATE
AND NATURAL GAS LIQUIDS
(BARRELS PER DAY)
Scott.......................... 34.95% 33,291 41,040
Beryl/Ness/Nevis............... 22.22/22.22/37.35 23,472 22,901
Fife/Fergus/Flora.............. 85.00/65.00/85.00 20,761 25,981
Telford........................ 31.42 10,603 10,548
Arbroath/Montrose/Arkwright.... 28.21 8,945 9,617
Ivanhoe/Rob Roy/Hamish......... 42.08 5,041 8,622
Durward/Dauntless.............. 28.00 5,012 2,677
Schiehallion................... 15.67 3,149 --
Hudson......................... 28.00 2,262 8,456
Other.......................... Various 2,917 2,949
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Total..................... 115,453 132,791
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NATURAL GAS (MCF PER DAY)
Everest/Lomond................. 18.67/16.67% 60,500 50,732
Beryl/Ness/Nevis............... 22.22/22.22/37.35 51,700 40,943
Indefatigable.................. 23.08 36,600 27,360
Leman.......................... 21.74 31,600 21,454
Davy/Bessemer.................. 27.78/23.08 29,000 41,292
Scott.......................... 34.95 17,200 18,811
Telford........................ 31.42 13,900 10,768
Other.......................... Various 10,500 14,444
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Total..................... 251,000 225,804
======= =======
</TABLE>
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Production from the Schiehallion and Flora Fields commenced in 1998. The
Corporation is developing several oil and gas fields in the United Kingdom North
Sea and is evaluating other discoveries.
NORWAY. The Corporation's activities in Norway are conducted through its
wholly-owned Norwegian subsidiary, Amerada Hess Norge A/S. The Corporation's
Norwegian operations accounted for crude oil and natural gas liquids production
of 28,322 and 31,173 net barrels per day in 1998 and 1997, respectively.
Approximately 83% of the 1998 production is from the Corporation's 28.09%
interest in the Valhall Field.
DENMARK. The Corporation is developing the South Arne Field in Denmark, in
which it has a 57.5% interest. Production is scheduled to commence in the third
quarter of 1999 at the rate of approximately 30,000 net barrels per day.
GABON. At December 31, 1998, the Corporation had a 10% interest in the
Rabi Kounga oil field onshore Gabon. The Corporation's share of production from
Gabon averaged 14,345 and 10,127 net barrels of crude oil per day in 1998 and
1997, respectively. In early 1999, the Corporation sold approximately 16% of its
investment in Gabon, which will reduce average annual production by
approximately 2,000 barrels of crude oil per day.
OTHER INTERNATIONAL. Production in Indonesia and Azerbaijan is currently
averaging approximately 2,500 and 1,500 barrels of crude oil per day,
respectively. Additional developments are underway or are planned in Indonesia
and Thailand.
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REFINING AND MARKETING
The Corporation has a 50% interest in a refining joint venture in the
United States Virgin Islands and has a fluid catalytic cracking facility in Port
Reading, New Jersey. The Corporation also markets petroleum products principally
on the East Coast of the United States. Of total refined products sold in 1998,
approximately 70% was obtained from the Corporation's refineries. The
Corporation purchased the balance from others under short-term supply contracts
and by spot purchases from various sources. Sales of refined products averaged
482,000 barrels per day in 1998 and 509,000 barrels per day in 1997.
REFINING JOINT VENTURE. On October 30, 1998, the Corporation and Petroleos
de Venezuela, S.A. (PDVSA) formed a 50% joint venture HOVENSA L.L.C. (HOVENSA)
to own and operate the refinery located in the United States Virgin Islands,
previously 100% owned by the Corporation. Pursuant to this transaction, PDVSA,
V.I., Inc. (PDVSA V.I.), a wholly-owned subsidiary of PDVSA, purchased a 50%
interest in the fixed assets of the Corporation's refinery. The Corporation's
Virgin Islands subsidiary and PDVSA V.I. each contributed their 50% interest in
the refinery fixed assets to HOVENSA, which is jointly owned by the
Corporation's subsidiary and PDVSA V.I.
In 1998, total refinery crude runs averaged 433,000 barrels per day for the
two months since inception of the joint venture and 419,000 barrels per day for
the ten months prior. Refinery crude runs were 411,000 barrels per day in 1997.
PDVSA supplies 155,000 barrels per day of Venezuelan Mesa crude oil to HOVENSA
pursuant to a long-term crude oil supply contract. The remainder was supplied
principally under contracts of one year or less with third parties and through
spot purchases on the open market. After sales of refined products by HOVENSA to
certain third parties, the Corporation may purchase up to 50% of HOVENSA's
remaining production of gasolines, distillates and intermediates and must
purchase 50% of the remaining production of residual fuel oil and certain other
products.
In 1999, HOVENSA will begin construction of a 58,000 barrel per day coker
to be completed in 2001. HOVENSA has a long-term supply contract with PDVSA to
purchase 115,000 barrels per day of Venezuelan heavy Merey crude oil on
completion of the coker.
PORT READING FACILITY. The Corporation owns and operates a fluid catalytic
cracking facility in Port Reading, New Jersey, which processes vacuum gas oil
and residual fuel oil and currently operates at a rate of approximately 60,000
barrels per day. The Port Reading facility primarily produces gasoline and
heating oil.
MARKETING. The Corporation markets refined petroleum products principally
on the East Coast of the United States to the motoring public, wholesale
distributors, industrial and commercial users, other petroleum companies,
commercial airlines, governmental agencies and public utilities. The Corporation
also markets natural gas to utilities and other industrial and commercial
customers and is currently expanding its energy marketing activities to include
electricity.
At December 31, 1998, the Corporation had 637 HESS(R) gasoline stations of
which approximately 75% were operated by the Corporation. Most of the
Corporation's stations are concentrated in densely populated areas, principally
in New York, New Jersey and Florida. Of the Corporation's stations, 335 have
convenience stores. The Corporation owns in fee approximately 65% of the
properties on which its stations are located. The Corporation also has 41
terminals located throughout its marketing area, with aggregate storage capacity
of approximately 44 million barrels. The Corporation is considering the sale of
approximately one-third of its United States storage network, principally the
terminals located on the Gulf Coast and along the Colonial Pipeline in the
southeast United States. The Corporation also expects to sell approximately 40
retail gasoline outlets located in Georgia and South Carolina.
COMPETITION AND MARKET CONDITIONS
The petroleum industry is highly competitive. The Corporation encounters
competition from numerous companies in each of its activities, particularly in
acquiring rights to explore for crude oil and natural gas and in the purchasing
and marketing of refined products. Many competitors are larger and have
substantially greater resources than the Corporation. The Corporation is also in
competition with producers and marketers of other forms of energy.
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The petroleum business involves large-scale capital expenditures and
risk-taking. In the search for new oil and gas reserves, long lead times are
often required from successful exploration to subsequent production. Operations
in the petroleum industry depend on a depleting natural resource. The number of
areas where it can be expected that hydrocarbons will be discovered in
commercial quantities is constantly diminishing and exploration risks are high.
Areas where hydrocarbons may be found are often in remote locations or offshore
where exploration and development activities are capital intensive and operating
costs are high.
The major foreign oil producing countries, including members of the
Organization of Petroleum Exporting Countries ("OPEC"), exert considerable
influence over the supply and price of crude oil and refined petroleum products.
Their ability or inability to agree on a common policy on rates of production
and other matters has a significant impact on oil markets and the Corporation.
The derivatives markets are also important in influencing the prices of crude
oil, natural gas and refined products. The Corporation cannot predict the extent
to which future market conditions may be affected by foreign oil producing
countries, the derivatives markets or other external influences.
OTHER ITEMS
The Corporation's operations may be affected by federal, state, local,
territorial and foreign laws and regulations relating to tax increases and
retroactive tax claims, expropriation of property, cancellation of contract
rights, and changes in import regulations, as well as other political
developments. The Corporation has been affected by certain of these events in
various countries in which it operates. The Corporation markets motor fuels
through lessee-dealers and wholesalers in certain states where legislation
prohibits producers or refiners of crude oil from directly engaging in retail
marketing of motor fuels. Similar legislation has been periodically proposed in
the U.S. Congress and in various other states. The Corporation, at this time,
cannot predict the effect of any of the foregoing on its future operations.
Compliance with various environmental and pollution control regulations
imposed by federal, state and local governments is not expected to have a
materially adverse effect on the Corporation's earnings and competitive position
within the industry. Capital expenditures for facilities, primarily to comply
with federal, state and local environmental standards, were $4 million in 1998
and the Corporation anticipates comparable capital expenditures in 1999. In
addition, the Corporation expended $9 million in 1998 for environmental
remediation, with a comparable amount anticipated for 1999.
The number of persons employed by the Corporation averaged 9,777 in 1998
and 9,216 in 1997.
Additional operating and financial information relating to the business and
properties of the Corporation appears in the text on pages 6 through 13 under
the heading "Exploration and Production," on pages 14 through 16 under the
heading "Refining, Marketing and Environmental Management," on pages 18 through
26 under the heading "Financial Review" and on pages 27 through 55 of the
accompanying 1998 Annual Report to Stockholders, which information is
incorporated herein by reference.*
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* Except as to information specifically incorporated herein by reference under
Items 1, 2, 5, 6, 7, 7A and 8, no other information or data appearing in the
1998 Annual Report to Stockholders is deemed to be filed with the Securities
and Exchange Commission (SEC) as part of this Annual Report on Form 10-K, or
otherwise subject to the SEC's regulations or the liabilities of Section 18 of
the Securities Exchange Act of 1934, as amended.
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ITEM 2. PROPERTIES
Reference is made to Item 1 and the operating and financial information
relating to the business and properties of the Corporation, which is
incorporated in Item 1 by reference.
Additional information relating to the Corporation's oil and gas operations
follows:
1. OIL AND GAS RESERVES
The Corporation's net proved oil and gas reserves at the end of 1998, 1997
and 1996 are presented under Supplementary Oil and Gas Data in the accompanying
1998 Annual Report to Stockholders, which has been incorporated herein by
reference.
During 1998, the Corporation provided oil and gas reserve estimates for
1997 to the Department of Energy. Such estimates are compatible with the
information furnished to the SEC on Form 10-K, although not necessarily directly
comparable due to the requirements of the individual requests. There were no
differences in excess of 5%.
The Corporation has no contracts or agreements to sell fixed quantities of
its crude oil production. In the United States, natural gas is sold through the
Company's marketing division to local distribution companies, and commercial,
industrial, and other purchasers, on a spot basis and under contracts for
varying periods. The Corporation's United States production is expected to
approximate 50% of its 1999 commitments under these contracts which total
approximately 675,000 Mcf per day. Third party purchases will be used to
supplement the Corporation's production in fulfilling its sales commitments and
in making spot sales. In the United Kingdom, approximately 60% of annual natural
gas production is sold under field specific take or pay contracts. Additionally,
approximately 300,000 Mcf per day of natural gas is sold by the Corporation's
United Kingdom marketing subsidiary to commercial and industrial companies,
generally under one year contracts, and to residential customers. After take or
pay sales, the Company could supply approximately one-third of United Kingdom
marketing sales commitments from its own production. The remainder will be
supplied by purchases of natural gas from third parties. The Corporation
attempts to minimize price and supply risks associated with its United States
and United Kingdom natural gas supply commitments by entering into purchase
contracts with third parties having adequate sources of supply, on terms
substantially similar to those under its commitments.
2. AVERAGE SELLING PRICES AND AVERAGE PRODUCTION COSTS
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<CAPTION>
1998 1997 1996
<S> <C> <C> <C>
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Average selling prices (Note A)
Crude oil, including condensate and natural gas
liquids (per barrel)
United States.................................... $12.02 $18.43 $16.49
Europe........................................... 13.15 19.20 20.23
Africa and Asia.................................. 12.35 18.48 20.95
Canada and Abu Dhabi............................. - - 17.91
Average.......................................... 12.83 19.01 19.41
Natural gas (per Mcf)
United States.................................... $ 2.08 $ 2.42 $ 2.13
Europe........................................... 2.28 2.46 2.17
Africa and Asia.................................. 1.10 1.05 -
Canada........................................... - - 1.35
Average.......................................... 2.18 2.44 2.08
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</TABLE>
Note A: Includes inter-company transfers valued at approximate market
prices and the effect of the Corporation's hedging activities.
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<TABLE>
<CAPTION>
1998 1997 1996
<S> <C> <C> <C>
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Average production (lifting) costs per barrel of
production (Note B)
United States.................................... $ 3.77 $ 4.49 $ 4.70
Europe........................................... 4.56 5.17 5.12
Africa and Asia.................................. 2.57 2.55 2.02
Canada and Abu Dhabi............................. - - 3.21
Average.......................................... 4.20 4.87 4.82
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</TABLE>
Note B: Production (lifting) costs consist of amounts incurred to operate
and maintain the Corporation's producing oil and gas wells, related equipment
and facilities (including lease costs of floating production and storage
facilities) and production and severance taxes. The average production costs per
barrel reflect the crude oil equivalent of natural gas production converted on
the basis of relative energy content (6 Mcf equals one barrel).
The foregoing tabulation does not include substantial costs and charges
applicable to finding and developing proved oil and gas reserves, nor does it
reflect significant outlays for related general and administrative expenses,
interest expense and income taxes.
3. GROSS AND NET DEVELOPED ACREAGE AND PRODUCTIVE WELLS AT DECEMBER 31, 1998
<TABLE>
<CAPTION>
DEVELOPED
ACREAGE PRODUCTIVE WELLS (NOTE A)
APPLICABLE TO -------------------------
PRODUCTIVE WELLS OIL GAS
(IN THOUSANDS) ------------ -----------
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GROSS NET GROSS NET GROSS NET
----- --- ----- --- ----- ---
<S> <C> <C> <C> <C> <C> <C>
United States............................. 1,871 520 2,220 641 376 221
Europe.................................... 539 137 264 61 138 28
Africa and Asia........................... 167 19 152 19 5 3
----- --- ----- --- ---- ---
Total........................... 2,577 676 2,636 721 519 252
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</TABLE>
Note A: Includes multiple completion wells (wells producing from different
formations in the same bore hole) totaling 34 gross wells and 17 net wells.
4. GROSS AND NET UNDEVELOPED ACREAGE AT DECEMBER 31, 1998
<TABLE>
<CAPTION>
UNDEVELOPED ACREAGE*
(IN THOUSANDS)
--------------------
GROSS NET
<S> <C> <C>
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United States........................................ 1,297 748
Europe............................................... 11,481 3,893
Africa, Asia and other............................... 31,142 13,034
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Total...................................... 43,920 17,675
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</TABLE>
* Includes acreage held under production sharing contracts.
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5. NUMBER OF NET EXPLORATORY AND DEVELOPMENT WELLS DRILLED
<TABLE>
<CAPTION>
NET EXPLORATORY WELLS NET DEVELOPMENT WELLS
------------------------ ------------------------
1998 1997 1996 1998 1997 1996
<S> <C> <C> <C> <C> <C> <C>
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Productive wells
United States........................ 3 5 8 22 27 22
Europe............................... 2 5 6 9 8 12
Africa, Asia and other............... 4 2 - 8 6 1
Canada and Abu Dhabi................. - - 7 - - 8
--- --- --- --- --- ---
Total........................... 9 12 21 39 41 43
--- --- --- --- --- ---
Dry holes
United States........................ 11 11 22 6 3 -
Europe............................... 4 8 8 - 1 2
Africa, Asia and other............... 4 1 2 - - -
Canada and Abu Dhabi................. - - 5 - - 1
--- --- --- --- --- ---
Total........................... 19 20 37 6 4 3
--- --- --- --- --- ---
Total..................................... 28 32 58 45 45 46
=== === === === === ===
</TABLE>
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6. NUMBER OF WELLS IN PROCESS OF DRILLING AT DECEMBER 31, 1998
<TABLE>
<CAPTION>
GROSS NET
WELLS WELLS
<S> <C> <C>
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United States.............................................. 8 4
Europe..................................................... 8 2
Africa, Asia and other..................................... 7 1
-- --
Total............................................ 23 7
== ==
</TABLE>
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7. NUMBER OF WATERFLOODS AND PRESSURE MAINTENANCE PROJECTS IN PROCESS OF
INSTALLATION AT DECEMBER 31, 1998 -- None
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ITEM 3. LEGAL PROCEEDINGS
On April 27, 1993, the Texas Natural Resource Conservation Commission
("TNRCC", then known as the Texas Water Commission) notified the Registrant of
alleged violations of the Texas Water Code as a result of alleged discharges of
hydrocarbon compounds into the groundwater in the vicinity of the Registrant's
terminal in Corpus Christi, Texas. Penalties provided for these violations
include administrative penalties not to exceed $10,000 per day. Although there
are many potential sources for hydrocarbon discharge in this vicinity, the
Registrant is continuing a groundwater assessment, corrective measures program
and other appropriate responses to these groundwater conditions. On December 9,
1994, the Executive Director of the TNRCC forwarded a Notice of Executive
Director's Preliminary Report and Petition for a TNRCC Order Assessing
Administrative Penalties and Requiring Certain Actions of Registrant. This
Notice recommended a $542,400 penalty be assessed and the Registrant be ordered
to undertake remedial actions at the Corpus Christi terminal. The Registrant is
engaging in settlement discussions with the TNRCC regarding this matter.
The Registrant is currently investigating allegations made to the
Registrant's internal reporting hotline of noncompliance at the Corpus Christi
terminal with federal and state environmental regulations. The Registrant's
investigation focuses on (i) onsite disposal of wastes and whether or not such
wastes should have been managed as a hazardous waste under the Resource
Conservation and Recovery Act and (ii) nonreporting or misreporting of the
results of wastewater discharge samples required to be obtained by the Corpus
Christi wastewater discharge permit. Registrant is cooperating with the TNRCC
and the United States Environmental Protection Agency (the "EPA") in the conduct
of its investigation. It is not possible at this
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time for Registrant to state whether any proceedings arising out of the
investigations will be commenced against the Registrant, or what claims would be
asserted or what relief would be sought.
On February 16, 1999, the Florida Department of Environmental Protection
("FLDEP") mailed the Registrant a proposed consent order relating to alleged
violations of the Industrial Wastewater Discharge Permit limits for the Tampa,
Florida terminal. The consent order proposes a fine of $1,060,000. The
Registrant has previously undertaken a program of corrective measures and other
appropriate responses to these alleged permit violations. The Registrant is
engaging in discussions with the FLDEP to resolve this matter and expects that
the amount, if any, ultimately paid by the Registrant will be substantially less
than the proposed fine.
The Corporation periodically receives notices from EPA that the Corporation
is a "potentially responsible party" under the Superfund legislation with
respect to various waste disposal sites. Under this legislation, all potentially
responsible parties are jointly and severally liable. For certain sites, EPA's
claims or assertions of liability against the Corporation relating to these
sites have not been fully developed. With respect to the remaining sites, EPA's
claims have been settled, or a proposed settlement is under consideration, in
all cases for amounts which are not material. The ultimate impact of these
proceedings, and of any related proceedings by private parties, on the business
or accounts of the Corporation cannot be predicted at this time due to the large
number of other potentially responsible parties and the speculative nature of
clean-up cost estimates, but is not expected to be material.
The Corporation is from time to time involved in other judicial and
administrative proceedings, including proceedings relating to other
environmental matters. Although the ultimate outcome of these proceedings cannot
be ascertained at this time and some of them may be resolved adversely to the
Corporation, no such proceeding is required to be disclosed under applicable
rules of the Securities and Exchange Commission. In management's opinion, based
upon currently known facts and circumstances, such proceedings in the aggregate
will not have a material adverse effect on the financial condition of the
Corporation.
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ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
During the fourth quarter of 1998, no matter was submitted to a vote of
security holders through the solicitation of proxies or otherwise.
EXECUTIVE OFFICERS OF THE REGISTRANT
The following table presents information as of February 3, 1999 regarding
executive officers of the Registrant:
<TABLE>
<CAPTION>
YEAR
INDIVIDUAL
BECAME AN
EXECUTIVE
NAME AGE OFFICE HELD* OFFICER
------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
John B. Hess............ 44 Chairman of the Board, Chief Executive Officer and 1983
Director
W. S. H. Laidlaw........ 43 President, Chief Operating Officer and Director 1986
Leon Hess............... 84 Chairman of the Executive Committee and Director 1969
J. Barclay Collins II... 54 Executive Vice President, General Counsel and 1986
Director
John Y. Schreyer........ 59 Executive Vice President, Chief Financial Officer and 1990
Director
Francis R. Gugen........ 49 Managing Director, Amerada Hess Limited 1999
(Corporation's British subsidiary)
Alan A. Bernstein....... 54 Senior Vice President 1987
F. Lamar Clark.......... 65 Senior Vice President 1990
John A. Gartman......... 51 Senior Vice President 1997
Neal Gelfand............ 54 Senior Vice President 1980
Gerald A. Jamin......... 57 Senior Vice President and Treasurer 1985
Daniel F. McCarthy...... 54 Senior Vice President 1995
Lawrence H. Ornstein.... 47 Senior Vice President 1995
F. Borden Walker........ 45 Senior Vice President 1996
</TABLE>
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* All officers referred to herein (other than Mr. Gugen who holds office
until his successor is duly chosen and qualified) hold office in accordance with
the By-Laws until the first meeting of the Directors following the annual
meeting of stockholders of the Registrant, and until their successors shall have
been duly chosen and qualified. Each of said officers was elected to the office
set forth opposite his name on May 6, 1998, except that Mr. Gugen was appointed
to his present office by the Board of Directors of Amerada Hess Limited on May
4, 1995 and was designated an executive officer of Registrant by the Board of
Directors of Registrant in its regular meeting on February 3, 1999. The first
meeting of Directors following the next annual meeting of stockholders of the
Registrant is scheduled to be held May 5, 1999.
Except for Messrs. Walker and Gartman, each of the above officers has been
employed by the Registrant or its subsidiaries in various managerial and
executive capacities for more than five years. Prior to his employment with the
Registrant in August 1996, Mr. Walker had been a general manager in the areas of
gasoline marketing, convenience store development and advertising at Mobil
Corporation. Mr. Gartman had been a vice president of Public Service Electric
and Gas Company in the area of energy marketing prior to his employment with the
Registrant in October 1997.
9
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PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON STOCK AND RELATED STOCKHOLDER MATTERS
Information pertaining to the market for the Registrant's Common Stock,
high and low sales prices of the Common Stock in 1998 and 1997, dividend
payments and restrictions thereon and the number of holders of Common Stock is
presented on page 26 (Financial Review), page 35 (Long-Term Debt) and on page 52
(Ten-Year Summary of Financial Data) of the accompanying 1998 Annual Report to
Stockholders, which has been incorporated herein by reference.
ITEM 6. SELECTED FINANCIAL DATA
A Ten-Year Summary of Financial Data is presented on pages 50 through 53 of
the accompanying 1998 Annual Report to Stockholders, which has been incorporated
herein by reference.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
The information required by this item is presented on pages 18 through 26
of the accompanying 1998 Annual Report to Stockholders, which has been
incorporated herein by reference.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The information required by this item is presented under "Derivative
Financial Instruments" on page 23 and in Footnote 13 on pages 39 and 40 of the
accompanying 1998 Annual Report to Stockholders, which has been incorporated
herein by reference.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The consolidated financial statements, including the Report of Ernst &
Young LLP, Independent Auditors, the Supplementary Oil and Gas Data (unaudited)
and the Quarterly Financial Data (unaudited) are presented on pages 26 through
49 of the accompanying 1998 Annual Report to Stockholders, which has been
incorporated herein by reference.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
------------------------
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Information relating to Directors is incorporated herein by reference to
"Election of Directors" from the Registrant's definitive proxy statement for the
annual meeting of stockholders to be held on May 5, 1999.
Information regarding executive officers is included in Part I hereof.
ITEM 11. EXECUTIVE COMPENSATION
Information relating to executive compensation is incorporated herein by
reference to "Election of Directors-Executive Compensation and Other
Information," other than information under "Compensation Committee Report on
Executive Compensation" and "Performance Graph" included therein, from the
Registrant's definitive proxy statement for the annual meeting of stockholders
to be held on May 5, 1999.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Information pertaining to security ownership of certain beneficial owners
and management is incorporated herein by reference to "Election of
Directors-Ownership of Voting Securities by Certain Beneficial Owners" and
"Election of Directors-Ownership of Equity Securities by Management" from the
Registrant's definitive proxy statement for the annual meeting of stockholders
to be held on May 5, 1999.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Information relating to this item is incorporated herein by reference to
"Election of Directors" from the Registrant's definitive proxy statement for the
annual meeting of stockholders to be held on May 5, 1999.
------------------------
10
<PAGE> 12
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(a) 1. AND 2. FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES
The financial statements filed as part of this Annual Report on
Form 10-K are listed in the accompanying index to financial statements
and schedules.
3. EXHIBITS
<TABLE>
<S> <C> <C>
3(1) -Restated Certificate of Incorporation of Registrant
incorporated by reference to Exhibit 19 of Form 10-Q of
Registrant for the three months ended September 30, 1988.
3(2) -By-Laws of Registrant incorporated by reference to Exhibit
3(2) of Form 10-K of Registrant for the fiscal year ended
December 31, 1985.
4(1) -Note and Warrant Purchase Agreement, dated June 27, 1991
(including the form of the Common Stock Purchase Warrant
expiring June 27, 2001, included as Exhibit B thereof)
incorporated by reference to Exhibit 4 of Form 10-Q of
Registrant for the three months ended June 30, 1991.
4(2) -Amendment, dated as of May 15, 1992 to the Note and Warrant
Purchase Agreement, dated June 27, 1991 (including the
form of the common stock purchase warrant expiring June
27, 2001, included as Exhibit B thereof), incorporated by
reference to Exhibit 19 of Form 10-Q of Registrant for the
three months ended June 30, 1992.
4(3) -Credit Agreement dated as of May 20, 1997 among Registrant,
the Subsidiary Borrowers thereunder, The Chase Manhattan
Bank as Administrative Agent and the Lenders party
thereto, incorporated by reference to Exhibit 4 of Form
10-Q of Registrant for the three months ended June 30,
1997.
-Other instruments defining the rights of holders of
long-term debt of Registrant and its consolidated
subsidiaries are not being filed since the total amount of
securities authorized under each such instrument does not
exceed 10 percent of the total assets of Registrant and
its subsidiaries on a consolidated basis. Registrant
agrees to furnish to the Commission a copy of any
instruments defining the rights of holders of long-term
debt of Registrant and its subsidiaries upon request.
10(1) -Extension and Amendment Agreement between the Government of
the Virgin Islands and Hess Oil Virgin Islands Corp.
incorporated by reference to Exhibit 10(4) of Form 10-Q of
Registrant for the three months ended June 30, 1981.
10(2) -Restated Second Extension and Amendment Agreement dated
July 27, 1990 between Hess Oil Virgin Islands Corp. and
the Government of the Virgin Islands incorporated by
reference to Exhibit 19 of Form 10-Q of Registrant for the
three months ended September 30, 1990.
10(3) -Technical Clarifying Amendment dated as of November 17,
1993 to Restated Second Extension and Amendment Agreement
between the Government of the Virgin Islands and Hess Oil
Virgin Islands Corp. incorporated by reference to Exhibit
10(3) of Form 10-K of Registrant for the fiscal year ended
December 31, 1993.
10(4) -Third Extension and Amendment Agreement dated April 15,
1998 and effective October 30, 1998 among Hess Oil Virgin
Islands Corp., PDVSA V.I., Inc., HOVENSA L.L.C. and the
Government of the Virgin Islands.
</TABLE>
11
<PAGE> 13
3. EXHIBITS (continued)
<TABLE>
<S> <C> <C>
10(5)* -Incentive Compensation Award Plan for Key Employees of
Amerada Hess Corporation and its subsidiaries incorporated
by reference to Exhibit 10(2) of Form 10-K of Registrant
for the fiscal year ended December 31, 1980.
10(6)* -Financial Counseling Program description incorporated by
reference to Exhibit 10(3) of Form 10-K of Registrant for
the fiscal year ended December 31, 1980.
10(7)* -Executive Long-Term Incentive Compensation and Stock
Ownership Plan of Registrant dated June 3, 1981
incorporated by reference to Exhibit 10(5) of Form 10-Q of
Registrant for the three months ended June 30, 1981.
10(8)* -Amendment dated as of December 5, 1990 to the Executive
Long-Term Incentive Compensation and Stock Ownership Plan
of Registrant incorporated by reference to Exhibit 10(9)
of Form 10-K of Registrant for the fiscal year ended
December 31, 1990.
10(9)* -Amerada Hess Corporation Pension Restoration Plan dated
January 19, 1990 incorporated by reference to Exhibit
10(9) of Form 10-K of Registrant for the fiscal year ended
December 31, 1989.
10(10)* -Letter Agreement dated August 8, 1990 between Registrant
and Mr. John Y. Schreyer relating to Mr. Schreyer's
participation in the Amerada Hess Corporation Pension
Restoration Plan incorporated by reference to Exhibit
10(11) of Form 10-K of Registrant for the fiscal year
ended December 31, 1991.
10(11)* -1995 Long-Term Incentive Plan, as amended, incorporated by
reference to Appendix A of Registrant's definitive proxy
statement dated March 28, 1996 for the Annual Meeting of
Stockholders held on May 1, 1996.
10(12)* -Stock Award Program for non-employee directors dated August
6, 1997 incorporated by reference to Exhibit 10(11) of
Form 10-K of Registrant for the fiscal year ended December
31, 1997.
10(13) -Asset Purchase and Contribution Agreement dated as of
October 26, 1998, among PDVSA V.I., Inc., Hess Oil Virgin
Islands Corp. and HOVENSA L.L.C. (including Glossary of
definitions) incorporated by reference to Exhibit 2.1 of
Form 8-K of Registrant dated October 30, 1998.
10(14) -Amended and Restated Limited Liability Company Agreement of
HOVENSA L.L.C. dated as of October 30, 1998 incorporated
by reference to Exhibit 10.1 of Form 8-K of Registrant
dated October 30, 1998.
13 -1998 Annual Report to Stockholders of Registrant.
21 -Subsidiaries of Registrant.
23 -Consent of Ernst & Young LLP, Independent Auditors, dated
March 19, 1999, to the incorporation by reference in
Registrant's Registration Statements on Form S-8 (Nos.
333-43569, 333-43571 and 33-65115) of its report relating
to Registrant's financial statements, which consent
appears on page F-2 herein.
27 -Financial Data Schedule (for electronic filing only).
</TABLE>
- --------------------------------------------------------------------------------
* These exhibits relate to executive compensation plans and arrangements.
(b) REPORTS ON FORM 8-K
A Current Report on Form 8-K dated October 30, 1998 was filed in the last
quarter of Registrant's fiscal year ended December 31, 1998 relating to the
disposition of a 50% interest in its refinery in St. Croix, U.S. Virgin Islands
to PDVSA V.I., Inc., and the formation of HOVENSA L.L.C., a joint venture which
owns and operates the refinery.
12
<PAGE> 14
SIGNATURES
PURSUANT TO THE REQUIREMENTS OF SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934, THE REGISTRANT HAS DULY CAUSED THIS REPORT TO BE SIGNED ON
ITS BEHALF BY THE UNDERSIGNED, THEREUNTO DULY AUTHORIZED, ON THE 19TH DAY OF
MARCH 1999.
AMERADA HESS CORPORATION
(REGISTRANT)
By /s/ JOHN Y. SCHREYER
................................
(JOHN Y. SCHREYER)
EXECUTIVE VICE PRESIDENT AND
CHIEF FINANCIAL OFFICER
PURSUANT TO THE REQUIREMENTS OF THE SECURITIES EXCHANGE ACT OF 1934, THIS
REPORT HAS BEEN SIGNED BELOW BY THE FOLLOWING PERSONS ON BEHALF OF THE
REGISTRANT AND IN THE CAPACITIES AND ON THE DATES INDICATED.
<TABLE>
<CAPTION>
SIGNATURE TITLE DATE
- --------------------------------------------------------------------------------------------------------------
<S> <C> <C>
Director, Chairman of
the Board and
Chief Executive Officer
/s/ JOHN B. HESS (Principal Executive Officer) March 19, 1999
.....................................................
(JOHN B. HESS)
Director, President and Chief
/s/ W.S.H. LAIDLAW Operating Officer March 19, 1999
.....................................................
(W.S.H. LAIDLAW)
Director March 19, 1999
.....................................................
(NICHOLAS F. BRADY)
/s/ J. BARCLAY COLLINS II Director March 19, 1999
.....................................................
(J. BARCLAY COLLINS II)
/s/ PETER S. HADLEY Director March 19, 1999
.....................................................
(PETER S. HADLEY)
/s/ LEON HESS Director March 19, 1999
.....................................................
(LEON HESS)
/s/ EDITH E. HOLIDAY Director March 19, 1999
.....................................................
(EDITH E. HOLIDAY)
/s/ WILLIAM R. JOHNSON Director March 19, 1999
.....................................................
(WILLIAM R. JOHNSON)
/s/ THOMAS H. KEAN Director March 19, 1999
.....................................................
(THOMAS H. KEAN)
/s/ FRANK A. OLSON Director March 19, 1999
.....................................................
(FRANK A. OLSON)
/s/ ROGER B. ORESMAN Director March 19, 1999
.....................................................
(ROGER B. ORESMAN)
</TABLE>
13
<PAGE> 15
<TABLE>
<CAPTION>
SIGNATURE TITLE DATE
- --------------------------------------------------------------------------------------------------------------
<S> <C> <C>
Director, Executive Vice President
and Chief Financial Officer
(Principal Accounting and
/s/ JOHN Y. SCHREYER Financial Officer) March 19, 1999
............................................................................................................
(JOHN Y. SCHREYER)
Director March 19, 1999
............................................................................................................
(WILLIAM I. SPENCER)
/s/ ROBERT N. WILSON Director March 19, 1999
............................................................................................................
(ROBERT N. WILSON)
/s/ ROBERT F. WRIGHT Director March 19, 1999
............................................................................................................
(ROBERT F. WRIGHT)
- --------------------------------------------------------------------------------------------------------------
</TABLE>
14
<PAGE> 16
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
INDEX TO FINANCIAL STATEMENTS AND SCHEDULES
<TABLE>
<CAPTION>
PAGE
NUMBER
<S> <C>
- --------------------------------------------------------------------------------
Statement of Consolidated Income for each of the three years
in the period ended December 31, 1998..................... *
Statement of Consolidated Retained Earnings for each of the
three years in the period ended December 31, 1998......... *
Consolidated Balance Sheet at December 31, 1998 and 1997.... *
Statement of Consolidated Cash Flows for each of the three
years in the period ended December 31, 1998............... *
Statement of Consolidated Changes in Common Stock and
Capital in Excess of Par Value for each of the three years
in the period ended December 31, 1998..................... *
Statement of Consolidated Comprehensive Income for each of
the three years in the period ended December 31, 1998..... *
Notes to Consolidated Financial Statements.................. *
Report of Ernst & Young LLP, Independent Auditors........... *
Quarterly Financial Data.................................... *
Supplementary Oil and Gas Data.............................. *
Consent of Independent Auditors............................. F-2
Schedules**
II -- Valuation and Qualifying Accounts................... F-3
</TABLE>
- --------------------------------------------------------------------------------
* The financial statements and notes thereto together with the Report of
Ernst & Young LLP, Independent Auditors, on pages 27 through 44, the Quarterly
Financial Data (unaudited) on page 26, and the Supplementary Oil and Gas Data
(unaudited) on pages 45 through 49 of the accompanying 1998 Annual Report to
Stockholders are incorporated herein by reference.
** Schedules other than Schedule II have been omitted because of the
absence of the conditions under which they are required or because the required
information is presented in the financial statements or the notes thereto.
F-1
<PAGE> 17
CONSENT OF INDEPENDENT AUDITORS
We consent to the incorporation by reference in this Annual Report (Form
10-K) of Amerada Hess Corporation of our report dated February 22, 1999,
included in the 1998 Annual Report to Stockholders of Amerada Hess Corporation.
Our audits also included the financial statement schedule of Amerada Hess
Corporation listed in Item 14(a). This schedule is the responsibility of the
Corporation's management. Our responsibility is to express an opinion based on
our audits. In our opinion, the financial statement schedule referred to above,
when considered in relation to the basic financial statements taken as a whole,
presents fairly in all material respects the information set forth therein.
We also consent to the incorporation by reference in the Registration
Statements (Form S-8, Nos. 333-43569, 333-43571 and 33-65115) pertaining to the
Amerada Hess Corporation Employees' Savings and Stock Bonus Plan, Amerada Hess
Corporation Savings and Stock Bonus Plan for Retail Operations Employees and the
1995 Long-Term Incentive Plan, of our report dated February 22, 1999, with
respect to the consolidated financial statements incorporated herein by
reference.
/s/ ERNST & YOUNG LLP
ERNST & YOUNG LLP
New York, N.Y.
March 19, 1999
F-2
<PAGE> 18
SCHEDULE II
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
VALUATION AND QUALIFYING ACCOUNTS
FOR THE YEARS ENDED DECEMBER 31, 1998, 1997 AND 1996
(IN THOUSANDS)
<TABLE>
<CAPTION>
ADDITIONS
---------------------
CHARGED
(CREDITED)
TO COSTS CHARGED DEDUCTIONS
BALANCE AND TO OTHER FROM BALANCE
DESCRIPTION JANUARY 1 EXPENSES ACCOUNTS RESERVES DECEMBER 31
- ----------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
1998
Reserves deducted in the balance sheet
from the assets to which they apply
Losses on receivables............ $ 2,840 $ 92 $3,858* $ 379 $ 6,411
======== ======== ====== ========= ========
Deferred income tax valuation.... $330,119 $ 28,994 $ -- $ 218,000** $141,113
======== ======== ====== ========= ========
1997
Reserves deducted in the balance sheet
from the assets to which they apply
Losses on receivables............ $ 2,840 $ 2,498 $ 154 $ 2,652 $ 2,840
======== ======== ====== ========= ========
Deferred income tax valuation.... $271,213 $ 58,906 $ -- $ -- $330,119
======== ======== ====== ========= ========
1996
Reserves deducted in the balance sheet
from the assets to which they apply
Losses on receivables............ $ 2,786 $ 860 $ 87 $ 893 $ 2,840
======== ======== ====== ========= ========
Deferred income tax valuation.... $325,739 $(54,526) $ -- $ -- $271,213
======== ======== ====== ========= ========
- ----------------------------------------------------------------------------------------------------------
</TABLE>
* Reflects increase resulting from acquisition of gas marketing customer
accounts.
** Reflects effect of reduction in deferred tax assets on formation of refining
joint venture.
F-3
<PAGE> 19
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<S> <C> <C>
3(1) -- Restated Certificate of Incorporation of Registrant
incorporated by reference to Exhibit 19 of Form 10-Q of
Registrant for the three months ended September 30, 1988.
3(2) -- By-Laws of Registrant incorporated by reference to Exhibit
3(2) of Form 10-K of Registrant for the fiscal year ended
December 31, 1985.
4(1) -- Note and Warrant Purchase Agreement, dated June 27, 1991
(including the form of the Common Stock Purchase Warrant
expiring June 27, 2001, included as Exhibit B thereof)
incorporated by reference to Exhibit 4 of Form 10-Q of
Registrant for the three months ended June 30, 1991.
4(2) -- Amendment, dated as of May 15, 1992 to the Note and
Warrant Purchase Agreement, dated June 27, 1991 (including
the form of the common stock purchase warrant expiring
June 27, 2001, included as Exhibit B thereof),
incorporated by reference to Exhibit 19 of Form 10-Q of
Registrant for the three months ended June 30, 1992.
4(3)* -- Credit Agreement dated as of May 20, 1997 among
Registrant, the Subsidiary Borrowers thereunder, The Chase
Manhattan Bank as Administrative Agent and the Lenders
party thereto, incorporated by reference to Exhibit 4 of
Form 10-Q of Registrant for the three months ended June
30, 1997.
-- Other instruments defining the rights of holders of
long-term debt of Registrant and its consolidated
subsidiaries are not being filed since the total amount of
securities authorized under each such instrument does not
exceed 10 percent of the total assets of Registrant and
its subsidiaries on a consolidated basis. Registrant
agrees to furnish to the Commission a copy of any
instruments defining the rights of holders of long-term
debt of Registrant and its subsidiaries upon request.
10(1) -- Extension and Amendment Agreement between the Government
of the Virgin Islands and Hess Oil Virgin Islands Corp.
incorporated by reference to Exhibit 10(4) of Form 10-Q of
Registrant for the three months ended June 30, 1981.
10(2) -- Restated Second Extension and Amendment Agreement dated
July 27, 1990 between Hess Oil Virgin Islands Corp. and
the Government of the Virgin Islands incorporated by
reference to Exhibit 19 of Form 10-Q of Registrant for the
three months ended September 30, 1990.
10(3) -- Technical Clarifying Amendment dated as of November 17,
1993 to Restated Second Extension and Amendment Agreement
between the Government of the Virgin Islands and Hess Oil
Virgin Islands Corp. incorporated by reference to Exhibit
10(3) of Form 10-K of Registrant for the fiscal year ended
December 31, 1993.
10(4) -- Third Extension and Amendment Agreement dated April 15,
1998 and effective October 30, 1998 among Hess Oil Virgin
Islands Corp., PDVSA V.I., Inc., HOVENSA L.L.C. and the
Government of the Virgin Islands.
10(5)* -- Incentive Compensation Award Plan for Key Employees of
Amerada Hess Corporation and its subsidiaries incorporated
by reference to Exhibit 10(2) of Form 10-K of Registrant
for the fiscal year ended December 31, 1980.
10(6)* -- Financial Counseling Program description incorporated by
reference to Exhibit 10(3) of Form 10-K of Registrant for
the fiscal year ended December 31, 1980.
</TABLE>
<PAGE> 20
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION
------- -----------
<S> <C> <C>
10(7)* -- Executive Long-Term Incentive Compensation and Stock
Ownership Plan of Registrant dated June 3, 1981
incorporated by reference to Exhibit 10(5) of Form 10-Q of
Registrant for the three months ended June 30, 1981.
10(8)* -- Amendment dated as of December 5, 1990 to the Executive
Long-Term Incentive Compensation and Stock Ownership Plan
of Registrant incorporated by reference to Exhibit 10(9)
of Form 10-K of Registrant for the fiscal year ended
December 31, 1990.
10(9)* -- Amerada Hess Corporation Pension Restoration Plan dated
January 19, 1990 incorporated by reference to Exhibit
10(9) of Form 10-K of Registrant for the fiscal year ended
December 31, 1989.
10(10)* -- Letter Agreement dated August 8, 1990 between Registrant
and Mr. John Y. Schreyer relating to Mr. Schreyer's
participation in the Amerada Hess Corporation Pension
Restoration Plan incorporated by reference to Exhibit
10(11) of Form 10-K of Registrant for the fiscal year
ended December 31, 1991.
10(11)* -- 1995 Long-Term Incentive Plan, as amended, incorporated by
reference to Appendix A of Registrant's definitive proxy
statement dated March 28, 1996 for the Annual Meeting of
Stockholders held on May 1, 1996.
10(12)* -- Stock Award Program for non-employee directors dated
August 6, 1997 incorporated by reference to Exhibit 10(11)
of Form 10-K of Registrant for the fiscal year ended
December 31, 1997.
10(13) -- Asset Purchase and Contribution Agreement dated as of
October 26, 1998, among PDVSA V.I., Inc., Hess Oil Virgin
Islands Corp. and HOVENSA L.L.C. (including Glossary of
definitions) incorporated by reference to Exhibit 2.1 of
Form 8-K of Registrant dated October 30, 1998.
10(14) -- Amended and Restated Limited Liability Company Agreement
of HOVENSA L.L.C. dated as of October 30, 1998
incorporated by reference to Exhibit 10.1 of Form 8-K of
Registrant dated October 30, 1998.
13 -- 1998 Annual Report to Stockholders of Registrant.
21 -- Subsidiaries of Registrant.
23 -- Consent of Ernst & Young LLP, Independent Auditors, dated
March 19, 1999, to the incorporation by reference in
Registrant's Registration Statements on Form S-8 (Nos.
333-43569, 333-43571 and 33-65115) of its report relating
to Registrant's financial statements, which consent
appears on page F-2 herein.
27 -- Financial Data Schedule (for electronic filing only).
</TABLE>
- --------------------------------------------------------------------------------
* These exhibits relate to executive compensation plans and arrangements.
<PAGE> 1
Exhibit 10(4)
Third Extension and Amendment
Agreement
Act NO. 6231
Passed by the Twenty-Second Legislature of
the Virgin Islands May 18, 1998
Approved by Governor Schneider
May 29, 1998
<PAGE> 2
- --------------------------------------------------------------------------------
ACT NO.6231
BILL NO 22-0259
TWENTY-SECOND LEGISLATURE OF THE VIRGIN ISLANDS
OF THE UNITED STATES
Regular Session
1998
To ratify the "Third Extension and Amendment Agreement" between the Government
of the Virgin Islands, Hess Oil Virgin Islands Corporation and PDVSA V.I., Inc.
and for other related purposes
--0--
BE IT ENACTED by the Legislature of the Virgin Islands:
SECTION 1. The Agreement, dated April 15, 1998, entitled "The Third
Extension and Amendment Agreement" between the Government of the Virgin Islands,
Hess Oil Virgin Islands Corporation, and PDVSA V.I., Inc., having been executed
by the Governor of the Virgin Islands, the Chairman of the Board of Hess Oil
Virgin Islands Corporation, and the Chairman of the Board of PDVSA V.I., Inc.,
respectively, is hereby ratified, and a copy thereof is appended hereto as
Appendix I and made a part hereof, and the sum of $1.2 million of the $8 million
described in Section 15 of Appendix I is hereby appropriated and shall be
utilized for territorial summer youth employment in the fiscal year ending
September 30, 1998 as follows: the Legislature of the Virgin Islands,
$400,000.00, and the Department of Labor, $800,000.00.
SECTION 2. The sum of $1 million is hereby appropriated to the Department
of Education from the $8 million received by the Government of the Virgin
Islands, pursuant to the Third Extension and Amendment Agreement between the
Government of the Virgin Islands, Hess Oil Virgin Islands Corporation and PDVSA
V.I., Inc. to provide equal vocational and technical education programs at all
public high schools in the Territory, including Central High School on St.
Croix, unless there is a particular public high school in a school district that
is specifically designated to provide vocational and technical education for
students in that district.
- --------------------------------------------------------------------------------
<PAGE> 3
- --------------------------------------------------------------------------------
2
Thus passed by the Legislature of the Virgin Islands on May 18, 1998.
Witness our Hands and the Seal of the Legislature of the Virgin Islands
this 22nd day of May, A.D., 1998.
/s/ Lorranine L. Berry
LORRANINE L. BERRY
President
/s/ Roosevelt St. C. David
ROOSEVELT ST. C. DAVID
Legislative Secretary
The above bill is hereby approved.
Witness my hand and the Seal of the
Government of the United States Virgin
Islands at Charlotte Amalie, St. Thomas,
this 29th day of May, A.D., 1998.
/s/ Roy L. Schneider
Roy L. Schneider, M.D.
Governor
- --------------------------------------------------------------------------------
<PAGE> 4
THIRD EXTENSION AND
AMENDMENT AGREEMENT
APRIL 15, 1998
THIS THIRD EXTENSION AND AMENDMENT AGREEMENT entered into by the
GOVERNMENT OF THE VIRGIN ISLANDS, herein called the "Government", and HESS OIL
VIRGIN ISLANDS CORP., a corporation existing under the laws of the Virgin
Islands, herein called "Hess", and PDVSA V.I., INC., a corporation existing
under the laws of the Virgin Islands, herein called "PDVSA VI, Inc.", on behalf
of themselves and a company to be formed as a limited liability company (to be
taxed as a partnership) under the laws of the Virgin Islands, herein called the
"Joint Venture":
WITNESSETH:
WHEREAS, the Government and Hess are parties to an Agreement relating to
the construction and operation of the Oil Refinery and Related Facilities in St.
Croix, U.S. Virgin Islands, approved by the Legislature of the Virgin Islands on
September 1, 1965 and amended, supplemented and clarified at various times by
mutual agreement of the parties (the "1965 Agreement"); and
WHEREAS, pursuant to the 1965 Agreement, to induce Hess to construct and
operate the Oil Refinery and Related Facilities in St. Croix and in order to
promote the public interest by economic development of the Virgin Islands, Hess
was, among other things, exempted from payment to the Government of certain
taxes, charges, fees and duties; and
WHEREAS, the 1965 Agreement specifically extended these exemptions not
only to Hess but also to such of its Affiliates as are engaged in constructing,
owning and/or operating the Oil Refinery and Related Facilities, as hereinafter
discussed; and
WHEREAS, the 1965 Agreement was amended and extended by the Extension and
Amendment Agreement approved by the Legislature of the Virgin Islands on May 7,
1981 (the "First Extension
1
<PAGE> 5
Agreement"), which provided, among other things, for the extension of the 1965
Agreement and for the payment by Hess of full corporate income taxes, real
property taxes on the Oil Refinery and Related Facilities fixed at $10,000,000
per year with increases as hereinafter described, export fees of 2 cents per
barrel on refinery products, and excise taxes on building materials imported for
use in refinery maintenance, and further provided for Hess to sell fuel to the
Virgin Islands Water and Power Authority at prices below market prices; and
WHEREAS, the 1965 Agreement, as amended and extended by the First
Extension Agreement, was further amended and extended by the Restated Second
Extension and Amendment Agreement dated July 27, 1990 and approved by the
Governor and the Legislature of the Virgin Islands the "Second Extension
Agreement") which, among other things, provided for the extension of the term of
the 1965 Agreement, as amended and extended by the First Extension Agreement,
and addressed matters relating to the construction of a fluid catalytic cracking
unit and the building of a vocational school in the Virgin Islands as
contemplated in the First Extension Agreement; and
WHEREAS, the 1965 Agreement, as amended and extended by the First
Extension Agreement and the Second Extension Agreement, was further amended by a
Technical Clarifying Amendment dated November 17, 1993 and approved by the
Governor and the Legislature of the Virgin Islands, which clarified that all
materials, including crude oil, feedstocks, blendstocks and petroleum products
brought into the Virgin Islands by third parties to be consumed, processed,
manufactured, blended or stored at the Oil Refinery and Related Facilities are
deemed to be brought into the Virgin Islands by Hess regardless of whether or
when title to such material passes to Hess and that such third parties are
exempt from taxes, charges, fees and duties to the same extent as Hess (the
"Technical Clarifying Amendment", together with the 1965 Agreement, as amended
and extended by the First Extension Agreement and the Second Extension
Agreement, hereinafter the "Agreement"); and
WHEREAS, prior and subsequent to the Second Extension Agreement and
Technical Clarifying Amendment, Hess has continued to incur substantial losses
from operations of the Oil Refinery and Related Facilities due to adverse market
conditions prevailing in the refining industry generally and also due to
2
<PAGE> 6
certain operational and economic factors adversely affecting the Oil Refinery
and Related Facilities particularly that have resulted in the creation of a
substantial tax loss carryforward; and
WHEREAS, the Government concurs with Hess that as a consequence of the
continuing substantial losses at the Oil Refinery and Related Facilities, it is
critical to the Oil Refinery and Related Facilities' survival and to its
continued operation and employment of personnel for Hess to conclude an
agreement with a strong oil producing country partner willing and able to commit
to substantial additional investments in the Oil Refinery and Related Facilities
and to make other arrangements necessary to strengthen the economic and
competitive position of the Oil Refinery and Related Facilities and enhance its
future profitability; and
WHEREAS, to that end, Hess, its parent company, Amerada Hess Corporation
("AHC"), and Petroleos de Venezuela, S.A. ("PDVSA"), the national oil company of
Venezuela, acting through its subsidiary, PDVSA Petroleo y Gas, S.A. ("PDV
P&G"), which is its major operating subsidiary holding all PDVSA's Venezuelan
exploration and production, refining and marketing assets, have entered into an
agreement in principle pursuant to which PDVSA VI, Inc., a wholly owned
subsidiary of PDVSA, will acquire a 50% interest in the Oil Refinery and Related
Facilities through the Joint Venture to be formed to own and operate the Oil
Refinery and Related Facilities, and to be owned 50% by Hess and 50% by PDVSA
VI, Inc.; and
WHEREAS, this proposed Third Extension and Amendment Agreement is a
necessary prerequisite to the formation of the Joint Venture and construction of
the Coker Project (as hereinafter defined) and the Government recognizes that
PDVSA, VI, Inc. must become a party to this Third Extension and Amendment
Agreement; and
WHEREAS, it was the original specific intent of the Government and Hess,
expressed in the 1965 Agreement, that all the obligations and benefits of the
Agreement would be available to any entity owned 50% by Hess and engaged in
ownership and/or operation of the Oil Refinery and Related Facilities, such as
the Joint Venture, and to evidence such intent the Government and Hess defined
the term "Affiliate" in the 1965 Agreement to
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<PAGE> 7
include any firm or corporation of which at least fifty percent (50%) of voting
rights or equity interest is owned directly or indirectly by Hess or AHC; and
WHEREAS, under the First Extension Agreement Hess is obligated to supply
annual bids for sales of low sulfur residual and distillate fuel oils to the
Virgin Islands Water and Power Authority ("VIWAPA") on the terms set forth
therein, an obligation which provides low sulfur fuel oils to VIWAPA at below
market prices and affords substantial savings and an assurance of supply to
VIWAPA; and
WHEREAS, without limiting the generality of the obligations and rights
which the Joint Venture will have under the Agreement, the Government has
requested, in view of the importance of this benefit to the Virgin Islands, that
the Joint Venture expressly confirm that it will continue to comply with this
obligation regarding low sulfur fuel oil sales to VIWAPA and expressly agree
that it will continue to extend this benefit to VIWAPA so long as VIWAPA is
owned 50% or more by the Government; and
WHEREAS, in connection with confirming such matters, it is appropriate to
conform the Agreement to the current agreement between Hess and VIWAPA regarding
the appropriate published reference for determining the price of low sulfur
residual and distillate fuel oils, which agreement was required due to the
cessation of publication of the original reference and is evidenced by a letter
agreement between Hess and VIWAPA dated October 21, 1988; and
WHEREAS, the Government has also requested the Joint Venture to confirm
that it will continue Hess' practice of selling to the Government of the Virgin
Islands, Department of Public Works, St. Croix Division and Department of
Property and Procurement, St. Croix Division their current requirements for
gasoline and diesel fuel f.o.b. the loading rack located at the Oil Refinery and
Related Facilities at the Joint Venture's posted rack price; and
WHEREAS, it is a condition of PDVSA VI, Inc.'s willingness and obligation
to conclude the transaction that the Joint Venture be permitted to utilize, for
the benefit of its members, the benefit of the net operating loss carryforward
of Hess as in effect immediately after giving effect to the closing of all
4
<PAGE> 8
transactions in connection with the formation of the Joint Venture; and
WHEREAS, such utilization of the Hess net operating loss carryforward by
the Joint Venture will afford the Joint Venture no greater Virgin Islands income
tax benefit or other Virgin Islands tax benefit than that which is available to
Hess in the absence of the Joint Venture; and
WHEREAS, Hess and PDV P&G have agreed in principle that PDV P&G or its
subsidiary or another affiliate of PDVSA (the "PDV Crude Supplier") will supply
crude oil, feedstocks, blendstocks and petroleum products to the Joint Venture
and, in connection therewith, the PDV Crude Supplier will store crude oil,
feedstocks, blendstocks, and petroleum products at the Oil Refinery and Related
Facilities and will sell and transfer title to such crude oil, feedstocks,
blendstocks, and petroleum products to the Joint Venture immediately prior to
the time such crude oil, feedstocks, blendstocks and petroleum products are used
for processing or blending, a principal effect of which will be to reduce the
Joint Venture's inventory carrying costs for crude oil, blendstocks, feedstocks
and petroleum products, which reduction in carrying costs will significantly
enhance the Joint Venture's profitability; and
WHEREAS, it was the intent of the Government and Hess, as expressed in the
Technical Clarifying Amendment, that for purposes of the Agreement all
materials, such as crude oil, feedstocks, blendstocks, and petroleum products,
brought into the Virgin Islands by a third party such as the PDV Crude Supplier
to be consumed, processed, manufactured, blended or stored at the Oil Refinery
and Related Facilities shall be deemed to have been brought into the Virgin
Islands by Hess or one of it Affiliates, regardless of which party is the
importer of record or whether or when title is transferred to Hess or such
Affiliate, and recognizing that such importation, storage and sale by the PDV
Crude Supplier is an integral part of the business plan for the Joint Venture
critically important to improving the financial results of the Oil Refinery and
Related Facilities, and recognizing further that it is a condition of PDVSA VI,
Inc.'s willingness and obligation to conclude the transaction to confirm the
foregoing intent, the Government acknowledges it is appropriate pursuant to the
terms of the Technical Clarifying Amendment and consistent with prevailing
Virgin Islands
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<PAGE> 9
administrative precedent that the PDV Crude Supplier shall not be subject to
Virgin Islands income taxes by reason of the importation, storage and sale of
such materials to be consumed, processed, manufactured, blended or stored at the
Oil Refinery and Related Facilities, and under the terms of the Technical
Clarifying Amendment, shall not have any liability for any Virgin Islands taxes,
excises, duties, gross receipts taxes, export fees, imposts or exactions or any
wharf age, tonnage, or ship dues by reason of such activity; and
WHEREAS, Hess and PDV P&G have agreed in principle that the Joint Venture
will construct a coker with an approximate capacity of 45,000 barrels per day
and related facilities and make such improvements to the Oil Refinery and
Related Facilities as are necessary to allow the refinery to process heavy
Venezuelan crude oil in a deep conversion mode (the coker, related facilities
and improvements, collectively, the "Coker Project"); and
WHEREAS, pursuant to the First Extension Agreement as modified and
confirmed by the Second Extension Agreement, Hess agreed to construct a fluid
catalytic cracking facility and obtained an option to construct, at its sole
discretion, a second fluid catalytic cracking unit, and also agreed that real
property taxes on the refinery would increase to $12,000,000 per year on
commencement of commercial production from the first fluid catalytic cracking
unit and to $14,000,000 per year on commencement of commercial production from
the second fluid catalytic cracking unit, if constructed; and
WHEREAS, current economics of the refining business and modern coker
technology make a coker more profitable than a second catalytic cracking
facility and accordingly the Government and Hess agree that construction of a
second catalytic cracking facility would not be economic for the Oil Refinery
and Related Facilities under current business conditions and would not be
undertaken; and
WHEREAS, Hess and PDVSA VI, Inc. have therefore requested that the Coker
Project replace the construction of the second catalytic cracking facility for
all purposes in the Agreement, including related provisions as to the
Government's facilitation of the granting of necessary permits and approvals and
to increased property taxes from the current $12,000,000 per year to $14,000,000
per year after commencement of commercial production
6
<PAGE> 10
from the unit, and the Government recognizes such request is appropriate in that
such project will be of greater economic significance to the Virgin Islands than
that envisioned for the second catalytic cracking facility and recognizes
further that the second catalytic cracking facility would not be economically
feasible; and
WHEREAS, the Government recognizes that it is a condition to PDV VI's
willingness and obligation to conclude the transaction, that the term of the
Agreement be extended to a date 20 years after commencement of commercial
production from the Coker Project, a term coincident with the 20 year term of a
crude oil supply contract to be entered into between the Joint Venture and the
PDV Crude Supplier for the supply of the heavy Venezuelan crude oil to be
processed in the Coker, which 20 year crude oil supply contract supports the
construction and is critical to the undertaking of the Coker Project; and
WHEREAS, the Government recognizes that the Joint Venture will afford
substantial and continuing benefits to the economy of the Virgin Islands by
strengthening the economic and competitive position of the refinery and
enhancing its profitability and by substantially preserving jobs, and that the
significant investments to be made for the Coker Project, which is expected to
take two to three years to build, will promote the public interest in the
economic development of the Virgin Islands, create a substantial number of
additional construction jobs and associated service-sector jobs and generate
substantial additional payrolls which will be spent in the Virgin Islands
economy and additional tax revenues for the Government of the Virgin Islands;
and
WHEREAS, it is the expressed intent of the Joint Venture that the current
managerial and operating employees of the Oil Refinery and Related Facilities
will continue to manage and operate the Oil Refinery and Related Facilities as
employees of the Joint Venture; and
WHEREAS, the Government has requested the Joint Venture to confirm, and to
cause its contractors to confirm, that each of them will continue the policy and
practice of Hess to encourage and foster, consistent with applicable law, the
employment and training of qualified Virgin Islands residents at the Oil
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<PAGE> 11
Refinery and Related Facilities and particularly in connection with the
construction of the Coker Project; and
WHEREAS, the Government has requested the Joint Venture to confirm that it
will continue and place increased emphasis on, consistent with applicable law,
the policy and practice of Hess to promote qualified Virgin Islands residents to
higher positions as they become available; and
WHEREAS, the Government, acting through the Virgin Islands Department of
Education and the Virgin Islands Department of Labor, wishes to encourage and
promote the development and improvement of vocational and technical skills among
the St. Croix and Virgin Islands workforce and to increase the level of reading
comprehension skills among the St. Croix and Virgin Islands workforce in order
to meet testing requirements for certain jobs and the Joint Venture has agreed
to assist in this regard; and
WHEREAS, the Joint Venture anticipates that in connection with the
construction of the Coker Project there may be a shortage of Virgin Islands
residents having the requisite skills to qualify for jobs on the construction of
the Coker Project as welders, electricians and instrument fitters and will
establish training programs to upgrade skills so that Virgin Islands residents
may qualify for such jobs, and also desires to establish an education program
for the reading comprehension skills required to pass the safety comprehension
test for employment in the construction of the Coker Project; and
WHEREAS, the St. Croix Vocational Technical Center currently does not have
the specialized classroom equipment required to conduct training classes for
Virgin Islands residents designed to upgrade skills in the craft classifications
for welders, electricians and instrument fitters and does not have the classroom
equipment and staff required to conduct an education program in reading
comprehension skills, and the Joint Venture will provide and install in
classrooms at the St. Croix Vocational Technical Center the equipment required
to conduct such classes, and to donate such equipment and the installation
thereof free of cost to the Government for continued use at the St. Croix
Vocational Technical Center and availability for the training and education of
future generations of Virgin Islands residents in such skills and
qualifications; and
8
<PAGE> 12
WHEREAS, the Joint Venture shall, in cooperation with and under the
auspices of the Virgin Islands Department of Education and the Virgin Islands
Department of Labor, establish at the St. Croix Vocational Training Center
training programs using classrooms so equipped by the Joint Venture, to upgrade
skills of welders, electricians and instrument fitters and a reading
comprehension program for the safety comprehension test, to recruit and hire the
four teachers required to conduct such classes and to pay salaries of such four
teachers for the period from the Effective Date to the date employment peaks on
the construction of the Coker Project; and
WHEREAS, the Government further recognizes that PDVSA VI, Inc. is
unwilling to proceed with the Joint Venture or the Coker Project without the
extension and amendment of the Agreement on terms set forth herein; and
WHEREAS, the Government, with the assistance and advice of competent
counsel, consultant Arthur D. Little, an independent financial consulting firm
engaged by the Government to complete an economic analysis, and whose report has
been received and transmitted to the Virgin Islands Legislature, and other
advisors, and after having the opportunity to discuss with Hess the current
conditions affecting the St. Croix refinery, the benefits of the proposed Joint
Venture and the requested modifications to the Agreement and the reasons
therefor, has conducted negotiations with the objective of facilitating the
construction of the Coker Project and sustaining the continued operation of the
Oil Refinery and Related Facilities in St. Croix on terms mutually beneficial to
and in the best interests of the Government and People of the Virgin Islands and
the Joint Venture;
NOW THEREFORE, in order to accomplish the foregoing, the Government, Hess,
PDVSA VI, Inc. and the Joint Venture mutually commit and agree to extend and
amend the Agreement as follows effective as provided in Section 16 below:
1. The Agreement and the effective period thereof, which is currently
scheduled to expire on June 1, 2010, is hereby extended to a date
twenty years after commencement of the manufacture of commercial
quantities of marketable products
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<PAGE> 13
from the Coker Project, as certified in writing by the Joint
Venture.
2. The term "Hess" as used in the Agreement shall be deemed to mean and
refer to the Joint Venture, and the term "Affiliate" shall be deemed
to mean and refer to Hess, AHC, PDVSA, PDVSA VI, Inc. and any other
firm or corporation of which at least fifty percent (50%) of the
voting rights or equity interest is owned, directly or indirectly,
by any or all of them. In order further to confirm the amendments
effected by the foregoing, the parties hereto understand and agree
that from and after the Effective Date, the Joint Venture shall bear
the same obligations and shall enjoy the same rights under the
Agreement, as amended herein, as Hess prior to the Effective Date.
Promptly after the formation of the Joint Venture, PDVSA VI, Inc.
and Hess shall cause the Joint Venture to execute this Third
Extension and Amendment Agreement to add the Joint Venture as a
party hereto, whereupon the Joint Venture shall become and be a
party to this Third Extension and Amendment Agreement as fully and
to the same extent as if it were originally a party hereto and shall
have all the rights and obligations of the Joint Venture hereunder,
without the necessity of any further act or deed.
3. Without limiting the generality of the foregoing, in order to
confirm for the benefit of the Virgin Islands an obligation which
provides VIWAPA low sulfur fuel oils at prices below market prices
and affords substantial savings and an assurance of supply, it is
expressly agreed that on and after the Effective Date the Joint
Venture shall fulfill its obligation under the First Extension
Agreement to submit bids on an annual basis for sales of low sulfur
residual fuel oils and low sulfur distillate fuel oils f.o.b. the
Oil Refinery and Related Facilities to VIWAPA or its successors for
use as fuel in its St. Thomas and St. Croix generating stations. It
is expressly agreed that the Joint Venture will continue to provide
such benefits to VIWAPA on and after the Effective Date during the
term of this Agreement so long as VIWAPA shall be owned 50% or more
by the Government. The Joint Venture's f.o.b. maximum price per
barrel for low sulfur residual and distillate fuel oils pursuant to
such bids shall not exceed the lower of:
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<PAGE> 14
(a) The Joint Venture's average landed monthly low sulfur crude
oil costs per barrel of low sulfur crude oil charged to the
processing units of the Oil Refinery and Related Facilities,
without adding thereto any refining costs, for the month of
any sales pursuant thereto, or
(b) For low sulfur No. 2 fuel oil, the average New York Reseller
Contract Barges Prices and for low sulfur residual fuel oils
the average Estimated New York Contract Cargo Prices, for the
same grades of low sulfur residual or distillate fuel oils, as
the case may be, as last published in the Oil Buyers' Guide on
date of loading, less Two Dollars ($2.00) per barrel (42
gallons per barrel).
The Oil Buyers' Guide is a weekly publication, which the Joint
Venture will maintain at its office. Should the Oil Buyers' Guide
cease publication, the parties will agree on a successor
publication. For the period of any such sales after the Effective
Date, the Joint Venture shall furnish appropriate certification on a
monthly basis as to the Joint Venture's average landed low sulfur
crude oil costs per barrel of low sulfur crude oil charged to the
processing units of the Oil Refinery and Related Facilities. After
the Effective Date, the Joint Venture shall operate oil barges and
bid on an annual basis for the transportation of low sulfur residual
and low sulfur distillate fuel oils from the Oil Refinery and
Related Facilities to the St. Thomas and St. Croix generating
stations of VIWAPA. The foregoing shall modify and replace Section 9
of the First Extension Agreement in its entirety.
4. The Joint Venture shall continue Hess's practice to supply the
Virgin Islands Department of Public Works, St. Croix Division's and
the Virgin Islands Department of Property and Procurement, St. Croix
Division's requirements for gasoline and diesel fuel by selling
gasoline and diesel fuel to the Government for the account of the
Virgin Islands, Department of Public Works, St. Croix Division and
the Virgin Islands Department of Property and Procurement, St. Croix
Division in tank trailer quantities f.o.b. the loading rack located
at the Oil Refinery and Related Facilities at the Joint Venture's
posted rack price on the date of such sale and
11
<PAGE> 15
such sales shall be exempt from the payment of gross receipts tax on
sales in the Virgin Islands.
5. For income tax purposes, each Joint Venture member's distributive
share of the Joint Venture's taxable income, up to but not exceeding
an aggregate amount, for all tax years, that is equal to HOVIC's
Available NOL (as hereinafter defined), shall not be subject to tax
and, solely for purposes of determining each such member's adjusted
tax basis in its interest in the Joint Venture, shall be treated as
income exempt from income tax. "HOVIC's Available NOL" shall mean
the amount of the net operating loss ("NOL") carryforwards available
to HOVIC on the first full day of operation of the Joint Venture,
determined as if such day was the last day of HOVIC's taxable year,
reduced to the extent that, in future years, such NOL carryforwards
expire unused. HOVIC's Available NOL shall be used exclusively as
described above, shall be reduced to the extent that it is so used
and shall not be subject to other limitations. Each member shall
determine its alternative minimum taxable income with regard to its
utilization of HOVIC's Available NOL.
6. In order to clarify and confirm the intent of the Technical
Clarifying Amendment, the PDV Crude Supplier shall not be subject to
U.S. Virgin Islands income taxation by reason of the bringing of
materials, including crude oil, feedstocks, blendstocks, or refined
petroleum products into the Virgin Islands to be consumed,
processed, manufactured, blended or stored at the Oil Refinery and
Related Facilities, nor by reason of the storage in the U.S. Virgin
Islands of such materials or the sale thereof to the Joint Venture.
The PDV Crude Supplier shall not be subject to any other Virgin
Islands taxes, excises, gross receipts taxes, franchise taxes and
similar fees, export fees, duties, imposts or exactions or any
wharfage, tonnage or ships dues by reason of such activity. The
provisions of this Section 6 shall be for the benefit of, and be
enforceable by, the PDV Crude Supplier.
7. Section 8(B) of the First Extension Agreement shall remain in full
force and effect except that the words "coker with an approximate
capacity of 45,000 barrels per day and related facilities and such
improvements as are necessary to
12
<PAGE> 16
allow the Oil Refinery and Related Facilities to process heavy crude
oil in a deep conversion mode" shall be substituted for the words
"second Fluid Catalytic Cracking Facility with supporting facilities
or a Hydro Cracking facility with supporting facilities and/or
petrochemical facilities." Section 5(B) of the First Extension
Agreement shall remain in full force and effect except that the
words "coker, related facilities and improvements" shall be
substituted for the words "catalytic or hydro cracking and
supporting facilities and/or petrochemical facilities." In order
further to confirm the amendments effected by the foregoing, it is
agreed that upon commencement of the manufacture of commercial
quantities of marketable products from the Coker Project, the date
of which shall be certified in writing to the Government by the
Joint Venture, the Joint Venture shall pay to the Government on a
prorated monthly basis real property taxes on the Oil Refinery and
Related Facilities owned by the Joint Venture and its Affiliates
including all improvements now or hereafter located thereon in the
fixed amount of $14,000,000.00 per calendar year. The Coker Project
shall, when constructed, and during the period of construction and
expansion contemplated thereby, be included in the term "Oil
Refinery and Related Facilities."
8. Recognizing that the Joint Venture will employ competent
professional architects and engineers to design and supervise the
construction and operation of the Coker Project, and that such
design, engineering, construction and operation shall be in
accordance with the highest standards for construction, operation
and safety, the Government will, consistent with applicable law,
issue on an expedited basis all permits, licenses and certificates,
and modifications thereof, and take such other action, required
under local laws, rules and regulations, relating to construction,
operation, safety and the protection of the environment, to enable
construction and operation of the Coker Project. The Government will
also support applications by the Joint Venture for approval of all
permits, licenses and certificates required from any agency or
department of the Federal Government.
9. The Joint Venture shall employ on the Effective Date employees of
HOVIC for the conduct of the business of the
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<PAGE> 17
Oil Refinery and Related Facilities on terms substantially similar
to, and no less favorable than, current employment arrangements,
including employee benefits.
10. The Joint Venture shall, consistent with applicable law, continue
Hess's policy of employing and training qualified Virgin Islands
residents, regardless of age, race, creed, color, sex, national
origin or ancestry, for technical, supervisory, managerial and
professional positions relating to the Oil Refinery and Related
Facilities and, in particular, will place increased emphasis on
promoting to higher positions, as such positions become available,
Virgin Islands residents who are qualified for such positions.
11. In connection with the Coker Project, it shall be the policy of the
Joint Venture to encourage and foster to the fullest extent
practicable and consistent with applicable law, the employment of
qualified Virgin Islands residents regardless of age, race, creed,
color, sex, national origin or ancestry, and the Joint Venture shall
require all independent contractors used in the Coker Project to
adhere to this policy in its hiring practices and to comply with all
applicable labor and employment laws of the Virgin Islands.
12. The Joint Venture shall provide and install in existing classroom
space at the St. Croix Vocational Technical Center, the specialized,
state-of-the-art equipment required to equip classrooms for the
conduct of training programs to upgrade the skills of Virgin Islands
residents for employment in each of the following job skill
classifications: welders, electricians and instrument fitters, one
classroom for each such skill training program, and shall also
provide and install in existing classroom space at the St. Croix
Vocational Technical Center the equipment required to equip one
classroom for the conduct of a reading comprehension education
program for the preparation of the safety comprehension test
required for employment in certain jobs, being a total of four
classrooms to be equipped as aforesaid for such skill upgrading and
reading comprehension programs. Such equipment and the cost of
installation thereof shall be donated by the Joint Venture to the
Government for the St. Croix Vocational Technical Center.
14
<PAGE> 18
13. It is further agreed in connection with the Coker Project and in
cooperation with the Virgin Islands Department of Labor and the
Virgin Islands Department of Education, that the Joint Venture will
establish training programs to upgrade the skills of Virgin Islands
residents for employment in construction on the Coker Project,
whether by the Joint Venture or independent contractors, in the
following positions where a shortage of Virgin Islands residents
having the requisite skills is anticipated: welders, electricians
and instrument fitters, and to establish an appropriate reading
comprehension education program for the safety comprehension test in
connection with the hiring of employees in construction on the Coker
Project, whether by Joint Venture or independent contractors. Such
training and education programs will be conducted in the classrooms
at the St. Croix Vocational School equipped for such programs as
provided in Section 12. The Joint Venture shall recruit and hire and
pay reasonable and comparable salaries for teachers for such
programs, being one teacher for each of the three skill training
classes for welders, electricians and instrument fitters and one
teacher for the reading comprehension education class, for the
period from the Effective Date to the date employment peaks on the
construction of the Coker Project, as certified in writing by the
Joint Venture. As used in Sections 10 through 12 and this Section
13, the term "Virgin Islands resident" shall mean any person who, at
the time he or she is considered for employment, is, and for a
continuous period of one year prior thereto has been, domiciled in
the U.S. Virgin Islands.
14. Capitalized terms not otherwise defined herein have the meanings
ascribed to them in the Agreement. Except as set forth above, all
terms and conditions of the Agreement shall continue in full force
and effect.
15. The Joint Venture shall, within ten (10) days of the Effective Date
of this Third Extension and Amendment Agreement, contribute
$8,000,000.00 to the Government of the Virgin Islands to be used for
grants to vocational education programs and Youth Summer Programs
and to assist in environmental studies and research at the
University of the Virgin Islands. Except for the payment stated
herein, no
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<PAGE> 19
stamp, transfer or other tax, fee, or payment shall be required to
be made to the Government of the Virgin Islands or any
instrumentality thereof by the Joint Venture, Hess, PDVSA VI, Inc.,
AHC, PDVSA or any affiliate of any of them in connection with the
consummation of all transactions relating to the formation of the
Joint Venture.
16. This Third Extension and Amendment Agreement shall have operative
effect commencing on the first date (the "Effective Date") upon
which both of the following shall have occurred: (i) the
ratification of this Third Extension and Amendment Agreement by the
Legislature of the Virgin Islands and (ii) the date of consummation
of all transactions in connection with the formation of the Joint
Venture, which date shall be certified in writing to the Government
by each of Hess and PDVSA VI, Inc.
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<PAGE> 20
WITNESS our signatures below the 15th day of April 1998.
GOVERNMENT OF THE
VIRGIN ISLANDS
By: /s/ Roy L. Schneider
------------------------------
Roy L. Schneider, M.D.
Governor
Attest:
/s/ [ILLEGIBLE]
- ------------------------------------
TERRITORY OF THE VIRGIN ISLANDS )
JUDICIAL DISTRICT OF ST. THOMAS & ST. JOHN ) ss.:
The foregoing instrument was acknowledged before me this 15th day of April
l998, by ROY L. SCHNEIDER, Governor of the Virgin Islands.
/s/ [ILLEGIBLE]
----------------------------------------
Notary Public
17
<PAGE> 21
HESS OIL VIRGIN ISLANDS CORP.
By: /s/ Leon Hess
---------------------------------
Leon Hess
Chairman of the Board and
President
Attest:
/s/ Carl T. Tursi
- --------------------------------------
Carl T. Tursi
Assistant Secretary
STATE OF NEW YORK )
ss:
COUNTY OF NEW YORK )
The foregoing instrument was acknowledged before me this 15th day of April 1998,
by LEON HESS, as Chairman of the Board and resident of HESS OIL VIRGIN ISLANDS
CORP. on behalf of the Corporation.
/s/ J. Barclay Collins II
----------------------------------------
Notary Public
J. BARCLAY COLLINS II
Notary Public, State of New York
No. 31-4825156
Qualified in New York County
Commission Expires February 15, 1999
18
<PAGE> 22
PDVSA VI, Inc.
By: /s/ Luis Urdaneta
------------------------------
Luis Urdaneta
President
Attest:
/s/ [ILLEGIBLE]
- -------------------------------------------
TERRITORY OF THE VIRGIN ISLANDS )
JUDICIAL DISTRICT OF ST. THOMAS & ST. JOHN ) ss.:
The foregoing instrument was acknowledged before me this 12th day of May 1998,
by Luis Urdaneta as President of PDVSA VI, Inc. on behalf of the corporation.
/s/ [ILLEGIBLE]
----------------------------------------
Notary Public
19
<PAGE> 1
Exhibit 13
AMERADA HESS
1998 ANNUAL REPORT
<PAGE> 2
- --------------------------------------------------------------------------------
EXPLORATION AND PRODUCTION
- --------------------------------------------------------------------------------
UNITED STATES
Amerada Hess brought the Baldpate Field on Garden Banks Blocks 259/260 in
the Gulf of Mexico on stream in the third quarter of 1998 using a
technologically innovative compliant tower. In the first half of 1999, Amerada
Hess will commence production from the Penn State discovery on Garden Banks
Block 216 through a sub-sea system tied back to the Baldpate production
facilities. Combined production from the Baldpate and Penn State Fields is
expected to exceed gross levels of 50,000 barrels of oil per day and 150,000 Mcf
of natural gas per day by the middle of this year. Amerada Hess is the operator
of Baldpate and Penn State with a 50% interest.
Northwest of the Baldpate Field, Amerada Hess discovered the Conger Field
(AHC 37.50%) on Garden Banks Block 215 in 1997. The Corporation plans to develop
the Conger Field with a sub-sea system tied back to the B platform on the nearby
Enchilada Field. Additional drilling is scheduled in 1999 as part of the Conger
development plan, as is design and procurement of required high-pressure,
sub-sea system components and materials. The Conger Field is expected to
commence production late in 2000.
In the Enchilada Field, production from the A platform began in 1997. The A
platform produces from Garden Banks Blocks 83, 84, 127 and 128, in each of which
Amerada Hess has a 25% interest. In the third quarter of 1998, production began
from the B platform on Garden Banks Block 172 (AHC 60%). Net production for
Amerada Hess from the Enchilada Field is expected to peak at 60,000 Mcf of
natural gas per day and 3,000 barrels of oil per day in 2000.
Amerada Hess drilled a discovery well in 1,750 feet of water on its
Northwestern prospect on Garden Banks Block 200 (AHC 50%) in 1998. The well
encountered 163 feet of net pay. The Company is formulating plans for
delineation drilling and evaluating development options for the prospect.
During 1998, Amerada Hess acquired 37 blocks in the Gulf of Mexico at a net
cost of $36 million. Thirty-five of the blocks are in water depths in excess of
600 feet.
Onshore activities were reduced in 1998 and concentrated on maximizing
value in North Dakota and the Gulf Coasts of Texas and Louisiana. Three
successful development wells were drilled in the Egypt Field (AHC
- --------------------------------------------------------------------------------
6
- --------------------------------------------------------------------------------
<PAGE> 3
GARDEN BANKS BLOCK 215
----------------------
GULF OF MEXICO
--------------
[Graphic Omitted]
<PAGE> 4
SCHIEHALLION
- -----------------
NORTH SEA
- --------------
[Graphic Omitted]
<PAGE> 5
- --------------------------------------------------------------------------------
75%) in Wharton County, Texas, bringing daily gross production to 30,000 Mcf of
natural gas per day and 800 barrels of oil per day.
In the Maurice Field in South Louisiana, two wells were drilled by the
Company, bringing gross daily production to 20,000 Mcf of natural gas per day
and 400 barrels of oil per day. The Company has a 58% interest in the Maurice
Field.
UNITED KINGDOM
Production began from three new developments in the United Kingdom North
Sea in 1998 and development of five new fields is expected to be completed in
1999.
The Schiehallion Field came on stream in the third quarter of 1998. Amerada
Hess Limited, the Company's British subsidiary, has a 15.67% interest in the
Schiehallion Field and its share of production is expected to reach 17,000
barrels of oil per day in 1999.
In the fourth quarter of 1998, production began from the Amerada Hess
Limited operated Flora Field. The Flora Field was developed by subsea tieback to
the Fife Field. Amerada Hess Limited has an 85% interest in both the Flora and
Fife Fields and its share of production from the Flora Field is expected to peak
at 12,000 barrels of oil per day this year.
The Bittern Field, located on Blocks 29/1a and 29/1b, will come on stream
late in 1999. Amerada Hess Limited manages the joint team that is developing and
will operate the production facilities. Amerada Hess Limited has a 29.12%
interest in the Bittern Field. Its share of production is expected to reach
17,000 barrels per day near the end of 1999.
The Renee and Rubie Fields were brought on stream in February 1999. The
fields are producing through the Amerada Hess Limited operated Ivanhoe/Rob Roy
facilities on Block 15/21. Amerada Hess Limited's share of production from the
Renee and Rubie Fields is expected to reach 4,000 barrels of oil per day in
1999.
The Buckland Field (AHL 14.07%) is scheduled to commence production in the
fourth quarter of 1999. Peak production for Amerada Hess Limited will be 4,000
barrels of oil per day and 5,000 Mcf of natural gas per day in 2000.
Phase two of the development of the Nevis Field (AHL 37.35%) was completed in
1998. Phase three will come on stream through the Beryl production facilities in
the third quarter of 1999. Amerada Hess Limited's share of production from Nevis
will peak at 12,000
- --------------------------------------------------------------------------------
9
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<PAGE> 6
- --------------------------------------------------------------------------------
barrels of oil per day and 13,000 Mcf of natural gas per day in 2000.
Amerada Hess Limited has a 27.68% interest in a number of natural gas
fields in the Easington Catchment Area, in the southern North Sea. Production
from these fields is expected to begin in 1999. Amerada Hess Limited expects to
receive peak production of 60,000 Mcf of natural gas per day from these fields.
An appraisal well is being drilled on the Blake Field located on Block
13/24b (AHL 30%) to further appraise previous discoveries. A decision to develop
the Blake Field has been delayed pending appraisal. Similarly, a development
decision on the discovery known as Goldeneye on Blocks 20/4b (AHL 40%) and
14/29a has been delayed. Late in 1998, the Company concluded that the Mariner
Field (AHL 26.67%) was not likely to be developed in the current oil price
environment. The Mariner Field contains a large but complex heavy oil reservoir.
The Company wrote-off its capitalized costs in the Mariner Field in the fourth
quarter of 1998.
Development plans are being formulated for two fields that are economic at
current prices. The Cook Field (AHL 28.46%) on Block 21/20a is likely to be
developed by tieback to the Anasuria floating production, storage and offloading
vessel. Peak production for Amerada Hess Limited is expected to reach 4,000
barrels of oil per day in 2001.
Consideration is being given to developing the Bell Field (AHL 23.08%) by
dual tiebacks to the Bessemer Field and the Callisto Field. Production from the
Bell Field is expected to peak at 15,000 Mcf of natural gas per day for Amerada
Hess Limited in 2000.
NORWAY
A large enhanced-recovery, waterflood project for the Valhall Field remains
under evaluation in light of the current low oil prices. Amerada Hess Norge A/S,
the Company's Norwegian subsidiary, has a 28.09% interest in the Valhall Field.
Net production for Amerada Hess Norge from the Valhall Field averaged 22,556
barrels of oil per day and 24,912 Mcf of natural gas per day in 1998.
- --------------------------------------------------------------------------------
10
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<PAGE> 7
- --------------------------------------------------------------------------------
DENMARK
Amerada Hess A/S, the Company's Danish subsidiary, is in the final stages of
developing the South Arne Field which it operates with a 57.48% interest. The
South Arne Field is scheduled to commence production in the third quarter of
this year and is expected to provide net production peaking at 30,000 barrels of
oil per day and 40,000 Mcf of natural gas per day in 2000. Successful
development drilling and the installation of waterflood facilities resulted in a
significant, positive reserve revision for the South Arne Field in 1998.
GABON
The Company acquired the minority interest in Amerada Hess Production Gabon,
its Gabonese subsidiary, in 1998. That subsidiary had a 10% interest in the Rabi
Kounga Field, the largest producing field in Gabon.
Amerada Hess Production Gabon has a 40% interest in the development of the
Atora Field. Production is expected to begin in 2000 and to reach a net level of
6,000 barrels of oil per day for Amerada Hess Production Gabon late in 2000.
AZERBAIJAN
Amerada Hess acquired a 1.68% interest in the AIOC Consortium in the
Caspian Sea in 1998. Net production for Amerada Hess currently is averaging
about 1,500 barrels of oil per day and is expected to peak at 12,000 barrels of
oil per day in 2007.
In January 1999, Amerada Hess and a partner acquired a 20% interest in the
Kursanga and Karabagly Fields onshore Azerbaijan, subject to final ratification
by the Azerbaijan Parliament. A plan to redevelop the fields is being completed
and is expected to be submitted for approval later this year.
THAILAND
Amerada Hess has a 15% interest in the Pailin gas field being developed
offshore Thailand. The field will come on stream late this year. Production for
Amerada Hess is expected to average 25,000 Mcf of natural gas per day in 2000
rising to a peak of 50,000 Mcf per day in 2002.
- --------------------------------------------------------------------------------
11
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<PAGE> 8
- --------------------------------------------------------------------------------
INDONESIA
Amerada Hess has a 30% interest in the Jabung PSC which contains the North
Geragai Field and the Makmur Field. Net production from those fields is
averaging an aggregate of 3,000 barrels of oil per day.
Elsewhere on the Jabung PSC, crude oil and natural gas discoveries were
made on the North Betara and Gemah prospects in 1998, with additional drilling
planned on Gemah in 1999. Following these discoveries and successful appraisal
drilling on Northeast Betara, gas reserves of about 300 Bcf net to Amerada Hess
have been found. Discussions are in progress for the sale of this gas.
Development plans are being finalized for the Betara complex and additional
drilling is planned for the Gemah prospect.
Amerada Hess is the operator and has a 50% interest in the Lematang
Production Sharing Contract in Southern Sumatra, on which a discovery well in
1997 tested at 30,000 Mcf of natural gas per day. A second well is planned on
this discovery, and development plans are being formulated for gross production
of up to 50,000 Mcf of natural gas per day.
An exploration well drilled on the Pangkah PSC (AHC 36%) tested at 20,000
Mcf of natural gas per day and 987 barrels of oil per day. The discovery is in
shallow water on the East Coast of Java. Development options are being studied.
Amerada Hess has reached agreement to acquire a 25% interest in the Jambi
Merang contract onshore South Sumatra. This block contains part of the Gelam
Field, a producing natural gas field, and also contains a gas discovery that is
currently being appraised.
MALAYSIA
Amerada Hess obtained a 70% interest in Block PM304 offshore Malaysia and
an 80% interest in Block SK306 offshore Sarawak in Malaysia. Both blocks contain
undeveloped discoveries, and the Company plans to acquire and process 3D seismic
on these blocks in 1999 prior to drilling in 2000.
BRAZIL
Amerada Hess acquired 32% interests in Blocks BC-8 in the Southern Campos
Basin and BS-2 in the Northern Santos Basin offshore Brazil early in 1999. These
blocks aggregate 7,500 square kilometers. This marks the first time that a
non-Brazilian company has been granted exploration acreage in the Campos Basin.
Amerada Hess will conduct a 3D seismic survey on these blocks in 1999.
- --------------------------------------------------------------------------------
12
- --------------------------------------------------------------------------------
<PAGE> 9
SOUTH ARNE
-------------
DENMARK
----------
[Graphic Omitted]
<PAGE> 10
HESS EXPRESS
- -----------------
TAMPA, FLORIDA
- --------------------
[Graphic Omitted]
<PAGE> 11
- --------------------------------------------------------------------------------
REFINING, MARKETING AND
ENVIRONMENTAL MANAGEMENT
- --------------------------------------------------------------------------------
REFINING
Refinery runs at the HOVENSA refinery in St. Croix, United States Virgin
Islands, which is 50% owned by Amerada Hess and 50% owned by Petroleos de
Venezuela, S.A., averaged 421,000 barrels per day in 1998 versus 411,000 barrels
per day in 1997. The fluid catalytic cracking unit operated at a rate in excess
of 130,000 barrels per day in 1998 and reached a rate as high as 135,000 barrels
per day during the year.
Plans are proceeding for the construction of a delayed coking unit at the
HOVENSA refinery. Current plans call for the unit to have capacity of 58,000
barrels per day. Permits are being acquired and it is estimated that
construction will take between two and three years. The coking unit will enable
the refinery to process lower cost, heavy crude oil that will improve financial
returns and make the refinery one of the most sophisticated in the world.
Operating rates at the Company's Port Reading fluid catalytic cracking unit
averaged 60,000 barrels per day in 1998. The unit makes gasoline and distillates
from feedstocks of vacuum gas oil and residual fuel oil.
MARKETING
The Company continues to build new, high volume HESS gasoline and HESS
EXPRESS convenience retail sites, upgrade existing gasoline stations and
convenience stores, make acquisitions in key geographic areas and increase the
number of independent HESS branded retailers. During 1998, 18 new HESS EXPRESS
stores were opened in key markets and construction began on nine others.
Thirteen retail sites were acquired in upstate New York markets. A total of 116
stations were upgraded. The largest of the new stations contain 5,000 square
foot HESS EXPRESS convenience stores and offer up to four fast food outlets.
Early in 1999, the Company reached agreement to purchase 10 retail sites,
which include convenience stores, in Florida. Agreement also was reached to
purchase 50 retail sites in central Pennsylvania from the Allentown area to as
far west as Harrisburg.
As part of the repositioning of assets, the Company is pursuing the sale of
approximately 40 retail marketing outlets in Georgia and in the Greenville,
South Carolina area.
- --------------------------------------------------------------------------------
15
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<PAGE> 12
- --------------------------------------------------------------------------------
The Company has entered into additional thruput agreements with other oil
companies under which products will be stored at HESS terminals along the East
Coast of the United States. In addition, the consummation of the joint venture
for the Virgin Islands refinery is resulting in transportation and storage
synergies with Petroleos de Venezuela.
In 1998, Amerada Hess pursued opportunities on the East Coast being created
by the deregulation of the natural gas and electricity markets. The Company's
historical fuel oil sales activities were expanded to market natural gas and
electricity. At year-end 1998, over 9,000 commercial and industrial customers
were under contract with Amerada Hess. Initial sales of electricity commenced in
New York and Pennsylvania as part of pilot projects. The Company's vision is to
be a leading provider of a range of energy products and related services in its
key East Coast markets.
ENVIRONMENTAL MANAGEMENT
Excellent environmental performance is an integral part of the Company's
goal of achieving superior financial and operating results while continuing to
maintain the highest ethical standards.
In 1998, Amerada Hess published its first Environmental, Health and Safety
Report.
In 1998, the Company also approved and began to implement an integrated
environmental management system (EMS) for all business activities. The objective
is to ensure that the Company's activities are conducted in a consistent,
environmentally responsible manner. An Environmental Council consisting of
senior line management was also formed.
As part of these efforts, the Company focused attention on its St. Lucia
terminal. In January 1999, the St. Lucia terminal was awarded ISO 14001
certification, the international standard for environmental management.
In addition, the Company maintained ISO 14001 certification for its United
Kingdom operations, which was originally received in 1997.
- --------------------------------------------------------------------------------
16
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<PAGE> 13
FINANCIAL REVIEW
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
- --------------------------------------------------------------------------------
Management's Discussion and Analysis of
Results of Operations and Financial Condition
CONSOLIDATED RESULTS OF OPERATIONS
The results of operations for 1998, excluding special items, amounted to a loss
of $196 million compared with income of $14 million in 1997 and $236 million in
1996.
The after-tax results by major operating activity for 1998, 1997 and 1996
are summarized below (in millions):
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------
1998 1997 1996
- -------------------------------------------------------------------------------
<S> <C> <C> <C>
Exploration and production $ (18) $ 258 $ 210
Refining, marketing
and shipping (18) (110) 181
Corporate (37) (16) (19)
Interest (123) (118) (136)
- -------------------------------------------------------------------------------
Income (loss) excluding
special items (196) 14 236
Special items (263) (6) 424
- -------------------------------------------------------------------------------
Net income (loss) $(459) $ 8 $ 660
===============================================================================
Net income (loss) per
share (diluted) $(5.12) $ .08 $7.09
===============================================================================
</TABLE>
COMPARISON OF RESULTS
Exploration and Production: Excluding special items, exploration and production
earnings decreased by $276 million in 1998, primarily due to substantially lower
worldwide crude oil selling prices and lower United Kingdom crude oil sales
volumes. Natural gas selling prices in the United States and United Kingdom were
also lower. Partially offsetting these factors were lower exploration expenses,
principally in the Gulf of Mexico and North Sea.
Exploration and production earnings increased by $48 million in 1997
compared with 1996. The increase primarily reflected higher average crude oil
and natural gas selling prices in the United States and higher natural gas
selling prices and a lower effective income tax rate in the United Kingdom.
The Corporation's average selling prices, including the effects of hedging,
were as follows:
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------------
1998 1997 1996
- --------------------------------------------------------------------------------
<S> <C> <C> <C>
Crude oil and natural gas
liquids (per barrel)
United States $ 12.02 $ 18.43 $ 16.49
Foreign 13.05 19.16 20.18
Natural gas (per Mcf)
United States 2.08 2.42 2.13
Foreign 2.26 2.46 2.03
================================================================================
</TABLE>
The Corporation's net daily worldwide production was as follows:
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------------
1998 1997 1996
- --------------------------------------------------------------------------------
<S> <C> <C> <C>
Crude oil and natural gas
liquids (barrels per day)
United States 44,920 43,950 50,125
Foreign 161,069 174,622 186,672
- --------------------------------------------------------------------------------
Total 205,989 218,572 236,797
- --------------------------------------------------------------------------------
Natural gas (Mcf per day)
United States 293,849 311,915 337,653
Foreign 282,628 257,339 347,013
- --------------------------------------------------------------------------------
Total 576,477 569,254 684,666
================================================================================
</TABLE>
The decrease in foreign crude oil production in 1998 largely reflects
maintenance related interruptions at three United Kingdom fields. United States
natural gas production was lower in 1998, principally reflecting first quarter
asset sales and natural decline. Foreign natural gas production increased in
1998 due to higher demand in the United Kingdom. Lower United States and foreign
production in 1997 was primarily due to asset sales in 1996. Limited production
began from several new fields in the second half of 1998 and the Corporation has
several developments which are expected to commence production in 1999. These
projects will add approximately 20% to 1999 production volumes.
- --------------------------------------------------------------------------------
18
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<PAGE> 14
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Depreciation, depletion and amortization charges were lower in 1998,
principally reflecting lower foreign crude oil production. In addition, the
Corporation had positive oil and gas reserve revisions at the end of 1997, which
reduced depreciation and amortization charges in 1998. Exploration expenses were
lower in 1998 due to reduced drilling in the United States and United Kingdom in
response to lower oil prices. Selling, general and administrative expenses
related to exploration and production operations were higher in 1998, primarily
due to the expansion of natural gas marketing in the United Kingdom and
increased foreign exploration and production activity outside of the North Sea.
The effective income tax rate on exploration and production earnings was
higher in 1998 than in 1997. The increase was primarily due to exploration
expenses in certain foreign areas outside of the United States and North Sea,
for which income tax benefits have not been currently provided. Although
international exploration expenses were comparable in both years, the impact was
greater in 1998 due to lower pre-tax exploration and production earnings. Both
years included the benefit of tax adjustments for reductions in the United
Kingdom statutory income tax rate. The effective income tax rate on exploration
and production earnings in 1997 was lower than in 1996, principally reflecting
lower Petroleum Revenue Taxes in the United Kingdom.
Earnings from exploration and production activities have been severely
affected by low crude oil prices. The Corporation cannot predict how long low
crude oil prices will continue. The Corporation had net additions to oil and gas
reserves at the end of 1998, however, constrained exploration and production
spending may negatively affect reserve additions in the future.
Refining, Marketing and Shipping: Excluding special items, the results of
refining, marketing and shipping operations amounted to losses of $18 million in
1998 and $110 million in 1997 compared with income of $181 million in 1996.
Refining margins were weak in both 1998 and 1997, and in addition, there was an
inventory write-down at the end of 1997. The results in both years were
negatively affected by relatively mild winter weather, which impacted heating
oil and residual fuel oil margins. Gasoline margins were adversely affected by
extremely competitive market conditions.
The Corporation is expanding its retail operations by purchasing and
constructing gasoline stations. The Corporation is also expanding its energy
marketing activities. The cost of operating the expanded retail and energy
marketing businesses increased selling, general and administrative expenses in
1998.
As described in Note 2 to the financial statements, on October 30, 1998,
the Corporation completed a refinery joint venture, HOVENSA L.L.C. (HOVENSA),
with a subsidiary of Petroleos de Venezuela, S.A. (PDVSA). The Corporation
accounts for its 50% investment in the joint venture using the equity method and
recorded a loss of $16 million for the two months since inception. The loss was
due to a write-down of inventory values at year-end. Income taxes or benefits
are not recorded on HOVENSA results due to available loss carryforwards.
Refining and marketing results include interest income of $8 million on the
PDVSA note received in connection with the formation of the joint venture.
Total refined product sales volumes amounted to 176 million barrels in
1998, 186 million barrels in 1997 and 181 million barrels in 1996. As a result
of the formation of, and equity accounting for, HOVENSA, sales made to third
parties are no longer included in the Corporation's reported revenues. Through
the first ten months of 1998, these sales accounted for 32 million barrels and
$600 million in revenues.
In 1997, refined product selling prices were lower than in 1996. The lower
selling prices in relation to the Corporation's inventory costs resulted in
lower margins on the sales of refined products and a reduction in inventory
values at year-end.
- --------------------------------------------------------------------------------
19
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<PAGE> 15
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Refined product margins continued to be severely depressed in early 1999,
reflecting oversupply of petroleum products due to competitive market conditions
and supply and demand factors, including the effects of weather. Refining and
marketing results will continue to be adversely affected as long as such
conditions prevail.
HOVENSA accounts for inventories on the last-in, first-out (LIFO) method.
Effective January 1, 1999, the Corporation also adopted LIFO for its refining
and marketing inventories.
The Corporation is considering the sale of several non-strategic U.S.
storage terminals and retail sites. The terminals are located on the Gulf Coast
and along the Colonial Pipeline in the southeast United States and represent
approximately one-third of the Corporation's United States storage network. The
Corporation expects to sell approximately 40 retail gasoline outlets located in
Georgia and South Carolina.
Corporate: Net corporate expenses amounted to $37 million in 1998, $16 million
in 1997 and $19 million in 1996. Administrative expenses were comparable in each
period. The variances in net expenses are primarily due to Corporate income tax
adjustments, including the impact of foreign source earnings on United States
income taxes and recognition of capital loss carryforwards in 1997.
Interest: After-tax interest expense increased by 4% in 1998 compared with a
decrease of 13% in 1997. The increase in 1998 reflects higher outstanding
borrowings, offset by lower interest rates and increased interest
capitalization. Assuming interest rates comparable to 1998, interest expense in
1999 is anticipated to be somewhat higher than in 1998, reflecting a higher
average debt balance.
Consolidated Operating Revenues: Sales and other operating revenues decreased by
approximately 20% in 1998, principally due to lower crude oil and refined
product selling prices and, to a lesser extent, lower sales volumes. Sales and
other operating revenues declined slightly in 1997 compared with 1996.
SPECIAL ITEMS
After-tax special items in 1998, 1997 and 1996 are summarized below (in
millions):
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------
REFINING,
EXPLORATION MARKETING
AND AND
TOTAL PRODUCTION SHIPPING
- -------------------------------------------------------------------------------
<S> <C> <C> <C>
1998
Gain (loss) on asset sales $ (50) $ 56 $(106)
Impairment of assets
and operating leases (198) (154) (44)
Severance (15) (15) --
------------------------------------------------------------------------------
Total $(263) $(113) $(150)
------------------------------------------------------------------------------
1997
Asset impairment $ (55) $ (55) $ --
Foreign tax refund 38 38 --
Gain on asset sale 11 11 --
------------------------------------------------------------------------------
Total $ (6) $ (6) $ --
------------------------------------------------------------------------------
1996
Gain on asset sales $ 421 $ 421 $ --
Litigation settlement 25 25 --
Asset write-downs (22) (22) --
------------------------------------------------------------------------------
Total $ 424 $ 424 $ --
==============================================================================
</TABLE>
- --------------------------------------------------------------------------------
20
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<PAGE> 16
- --------------------------------------------------------------------------------
The 1998 special items include a loss of $106 million on the sale of 50% of
the St. Croix refinery and formation of the HOVENSA joint venture. The
Corporation also had gains of $56 million on the sale of oil and gas assets in
the United States and Norway. Asset impairment in 1998 includes $44 million for
the Corporation's crude oil storage terminal in St. Lucia. The terminal's value
was affected by reduced storage requirements as a result of the crude oil supply
provisions of the HOVENSA joint venture. In addition, the Corporation recorded
$42 million for the reduction in carrying value of certain exploration and
production assets, including $29 million for its share of asset impairment of
Premier Oil plc, an equity affiliate. It is estimated that these charges will
reduce future expenses by approximately $19 million in 1999 and $9 million in
2000.
The Corporation also recorded a charge of $77 million for the decline in
value of fixed-price drilling service contracts and $35 million for the
impairment of a North Sea oil discovery. The Corporation's accrual for
fixed-price drilling service contracts includes amounts that will be paid, and
otherwise would have been expensed, in 1999 and 2000 of approximately $30
million and $47 million (after income tax effect). Severance of $15 million was
also recorded in 1998 and is expected to result in an annual benefit of a
comparable amount. Approximately $2 million of severance has been paid in 1998
and substantially all of the remainder will be paid in 1999.
The 1997 special items include an after-tax charge of $55 million for the
reduction in carrying values and provision for future costs of two United
Kingdom North Sea oil fields. Approximately 70% of the remaining crude oil from
these fields was produced during 1998 and the balance will be produced in 1999.
Other 1997 special items included income of $38 million from a refund of United
Kingdom Petroleum Revenue Taxes and a gain of $11 million on the sale of a
United States natural gas field.
The net gain on asset sales in 1996 of $421 million reflected the sale of
the Corporation's Canadian operations, certain United States and United Kingdom
producing properties and Abu Dhabi assets. The other 1996 special items included
income from the settlement of litigation on the right to drill certain South
Atlantic leases and a charge principally to reduce the carrying values of
certain United States undeveloped leases.
See Note 3 to the financial statements for additional information on the
special items affecting the Corporation's earnings.
LIQUIDITY AND CAPITAL RESOURCES
Net cash provided by operating activities, including changes in operating assets
and liabilities, amounted to $519 million in 1998, $1,250 million in 1997 and
$808 million in 1996. The variance between 1998 and 1997 was largely due to
operating results and working capital changes, principally reduced inventory
balances in 1997 and increased prepaid expenses in 1998.
The Corporation received proceeds of approximately $370 million on
finalization of the refining joint venture, including $307 million for inventory
and other working capital sold to HOVENSA and $62.5 million from PDVSA
representing the cash portion of the purchase price. These amounts are reflected
in proceeds from asset sales in the statement of cash flows. The Corporation
also recorded a note for $562.5 million bearing interest at 8.46% per annum. In
addition, the sale of three oil and gas properties in the United States and
Norway generated proceeds of $98 million in 1998. In the first quarter of 1999,
the Corporation also sold onshore United States natural gas properties for $54
million.
In connection with its asset rationalization program, the Corporation
periodically reviews and considers for sale those assets that are
underperforming or non-strategic. When determining its capital budget, the
Corporation takes into account the estimated proceeds from these anticipated
asset sales, as well as estimates of cash to be provided by operations. In 1998,
these amounts totaled $987 million, consisting of $519 million in cash provided
by operating activities and $468 million in proceeds from major asset sales.
- --------------------------------------------------------------------------------
21
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<PAGE> 17
- --------------------------------------------------------------------------------
Total debt was $2,652 million at December 31, 1998 compared with $2,127
million at December 31, 1997. The debt to capitalization ratio increased to
50.1% from 39.8% at year-end 1997. At December 31, 1998, floating rate debt
amounted to 32% of total debt, including the effect of interest rate conversion
(swap) agreements. At December 31, 1998, the Corporation had $805 million of
additional borrowing capacity available under its long-term revolving credit
agreement, $300 million under a committed revolving credit line maturing in
August 1999 and additional unused lines of credit under uncommitted arrangements
with banks of $362 million. The existing borrowing arrangements, including
restrictive covenants, are more fully described in Note 7 to the financial
statements.
During 1998, the Corporation completed private placements of $225 million
of fixed rate debt with three insurance companies having a weighted average
maturity of 7.4 years. The Corporation also completed the sale and leaseback of
its interests in the production platforms and related facilities of two Gulf of
Mexico producing properties. These transactions have been accounted for as
financings.
In 1998 and 1997, the Corporation sold subsequent year crude oil production
for $249 million and $174 million, respectively, which is recorded as deferred
revenue and resulted in reduced debt at the end of each year.
During 1998, the Corporation purchased 1,071,500 shares of common stock for
$56 million under its $250 million stock repurchase program which is scheduled
to expire on March 31, 1999. Through December 31, 1998, $190 million has been
spent on repurchased shares under this program.
The Corporation conducts foreign exploration and production activities in
the United Kingdom, Norway, Denmark, Gabon, Indonesia, Azerbaijan and in other
countries. Therefore, the Corporation is subject to the risks associated with
foreign operations. These risks include the effects of changes in values of
currencies on the financial statements. However, the effect of foreign currency
translation on the Corporation's earnings and stockholders' equity has not been
material and has not affected its liquidity or ability to raise capital.
Although the financial problems in Asia and other parts of the world have
contributed to the worldwide decline in crude oil prices, the Asian financial
problems have not had a material adverse effect on the carrying values of the
Corporation's foreign investments.
CAPITAL EXPENDITURES
The following table summarizes the Corporation's capital expenditures in
1998, 1997 and 1996 (in millions):
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------------
1998 1997 1996
- --------------------------------------------------------------------------------
<S> <C> <C> <C>
Exploration and production
Exploration $ 242 $ 286 $ 236
Development 915 679 512
Acquisitions 150 193 40
- --------------------------------------------------------------------------------
1,307 1,158 788
Refining, marketing and shipping 132 188 73
- --------------------------------------------------------------------------------
Total $1,439 $1,346 $ 861
================================================================================
</TABLE>
Development expenditures include approximately $690 million and $460
million in 1998 and 1997, respectively, for major new oil and gas developments.
Acquisitions in 1998 reflect $100 million for exploration and production
interests in Azerbaijan and $50 million for an increased interest in a
consolidated subsidiary with proved crude oil reserves and exploration licenses
in Gabon. Acquisitions in 1997 principally represent purchases of developed and
undeveloped oil and gas properties in the United Kingdom. Refining and marketing
expenditures in 1997 include the purchase of a chain of retail marketing
properties in Florida.
- --------------------------------------------------------------------------------
22
- --------------------------------------------------------------------------------
<PAGE> 18
- --------------------------------------------------------------------------------
Oil and gas development expenditures are expected to be lower in 1999 as
new fields come onstream and the Corporation has significantly reduced planned
exploration expenditures due to lower crude oil prices. As a result, the
Corporation expects its total capital expenditures, excluding acquisitions, if
any, to approximate $900 million in 1999. These expenditures will be financed by
internally generated funds and external borrowings.
DERIVATIVE FINANCIAL INSTRUMENTS
The Corporation is exposed to market risks related to volatility in the
selling prices of crude oil, natural gas and refined products, as well as to
changes in interest rates and foreign currency values. Derivative instruments
are used to reduce the risks of these price and rate fluctuations and the
Corporation has guidelines for, and controls over, the use of such instruments.
Futures, forwards, options and swaps are used to reduce the effects of
changes in the selling prices of crude oil, natural gas and refined products.
These instruments fix the selling prices of a portion of the Corporation's
products and the related gains or losses are an integral part of the
Corporation's selling prices. At December 31, the Corporation had open hedge
positions equal to 3% of its estimated 1999 United States natural gas
production. In addition, the Corporation had hedges covering 9% of its refining
and marketing inventories. As market conditions change, the Corporation will
adjust its hedge positions.
The Corporation owns an interest in a partnership that trades energy
commodities and energy derivatives. The accounts of the partnership are
consolidated with those of the Corporation. The Corporation also engages in
trading for its own account.
The Corporation uses value at risk to estimate the potential effects of
changes in fair values of derivatives and other instruments used in hedging
activities and derivatives and commodities used in trading activities. This
method determines the potential one-day change in fair value with 95%
confidence. The analysis is based on historical volatility, historical
simulation and other assumptions. The Corporation estimates that at December 31,
1998, the value at risk related to hedging activities, excluding the physical
inventory hedged, was $1 million ($5 million at December 31, 1997). During 1998,
the average value at risk for hedging activities was $4 million, the high was $5
million and the low was $1 million. The value at risk on trading activities,
predominantly partnership trading, was $4 million at December 31, 1998 ($2
million at December 31, 1997). During 1998, the average value at risk for
trading activities was $5 million, the high was $6 million and the low was $3
million.
The Corporation also uses interest-rate conversion agreements to reduce
exposure to rising interest rates. At December 31, 1998, the Corporation has
$400 million of notional-value, interest-rate conversion agreements that
effectively reduce its percentage of floating rate debt from 47% to 32% ($300
million at December 31, 1997). These agreements relate to the Corporation's
outstanding debt of $2,652 million, which together with the interest-rate swaps
has a fair value of $2,735 million at December 31, 1998. A 10% change in
interest rates would change the fair values of debt and related swaps by $64
million at December 31, 1998 ($48 million at December 31, 1997).
The Corporation also hedges a portion of its exposure to fluctuating
foreign exchange rates, principally the Pound Sterling. Generally, the
Corporation uses forward contracts to fix the exchange rate on a portion of the
currency used in its North Sea operations. The possible change in fair value of
these contracts from a 10% change in the exchange rate is estimated to be $10
million at December 31, 1998 ($18 million at December 31, 1997). See Note 13 to
the financial statements for additional information on financial instruments,
hedging and trading activities.
- --------------------------------------------------------------------------------
23
- --------------------------------------------------------------------------------
<PAGE> 19
- --------------------------------------------------------------------------------
YEAR 2000
Some older computer software and embedded computer systems use two digits rather
than four to reflect dates used in performing calculations. Because these
computer programs and embedded systems may not properly recognize the year 2000,
errors may result causing potentially serious disruptions. In addition, third
parties with which the Corporation does business face the same problems.
The Corporation has a worldwide program to identify software and hardware
that is not year 2000 compliant. The Corporation is also determining the year
2000 status of major vendors and customers and has begun contingency planning.
The Corporation's year 2000 project is jointly managed by its Chief Information
Officer and its Vice President of Internal Audit.
Status of year 2000 project: Since 1995, the Corporation has been installing new
financial and business systems as part of its reengineering project. Although
the primary purpose of the project is to increase efficiency and effectiveness,
the new software is year 2000 compliant. These new systems have replaced, or
will replace, approximately 70% of noncompliant software. The final phase of the
new software installation is scheduled for completion in the second quarter of
1999.
The Corporation has assessed its remaining software. Remediation of the
remaining software is largely complete and testing of changes is in progress.
Testing is scheduled to be complete by the third quarter of 1999. The
Corporation has completed approximately 70% of this portion of the project at
December 31. The Corporation principally uses external consultants on this phase
of the project.
There are embedded computer systems used throughout the Corporation's
operations. The Corporation has hired consultants to evaluate embedded systems.
The inventory and assessment phases will be completed at the end of the first
quarter of 1999. Remediation of critical systems, where required, should finish
in the second quarter of 1999. Remediation of all other systems, where required,
will be completed in the third quarter. At December 31, assessment and
remediation of embedded computer systems is approximately 65% complete.
The Corporation has also undertaken a supplier and customer analysis of
year 2000 readiness. The identification process is complete. Communication with
third parties to assess their progress in addressing year 2000 problems is in
progress. The third party analysis will be completed by the end of the second
quarter of 1999 and is approximately 60% complete at December 31.
Costs: The new systems that replace approximately 70% of noncompliant software
will have a total cost of approximately $50 million (of which approximately 85%
has been expended at December 31). The Corporation expects to spend an
additional $12 million for remediation of remaining systems, primarily for
outside consultants, which is being expensed as incurred. To date, the
Corporation has expended approximately $6 million of the expected total.
The Corporation has not deferred ongoing information technology projects
because of year 2000 efforts.
- --------------------------------------------------------------------------------
24
- --------------------------------------------------------------------------------
<PAGE> 20
- --------------------------------------------------------------------------------
Risks: There are uncertainties inherent in the year 2000 problem, partially
resulting from the readiness of customers and suppliers. The failure to correct
material year 2000 problems could interrupt business and operations.
Uncorrected, these interruptions could have a material effect on the
Corporation's financial position and results of operations. Consequently, the
Corporation cannot determine whether year 2000 failures will materially affect
its financial position or results of operations. However, the objective of the
Corporation's year 2000 project is to reduce these risks.
Contingency planning: Contingency plans are necessary to ensure that risks
associated with year 2000 are mitigated. In the normal course of business, the
Corporation has developed contingency plans to ensure that it has alternate
suppliers for critical materials and equipment and that production of crude oil,
natural gas and refined products can be sold. The Corporation is in the design
phase of contingency planning for year 2000 and expects to use existing
contingency plans in this process. Contingency planning will be completed by the
third quarter of 1999 and updated at year-end, if appropriate.
In addition, the Corporation has engaged external consultants to review and
benchmark the progress of its year 2000 project.
Safe Harbor: Certain information in this section on year 2000 is forward
looking. This includes projected costs, time tables for, and percentages of,
completion of projects and possible effects. These disclosures are based on the
Corporation's current understanding and assessment of the year 2000 problem.
Assumptions used, such as availability of resources, and the status of its year
2000 assessment and remediation projects may change. In addition, suppliers and
customers may fail to be ready for year 2000. Consequently, actual results may
differ from these disclosures.
ENVIRONMENTAL MANAGEMENT
The Corporation is aware of its environmental responsibilities and the relevant
environmental regulations with which it must comply at the federal, state and
local level. Accordingly, the Corporation incurs ongoing operating costs and
capital investment. The Corporation believes that it has made the necessary
expenditures to comply with existing legislation and that it is well positioned
to meet currently proposed regulations.
The Corporation continues to focus on energy conservation, pollution
control and waste minimization and treatment. There are also programs for
compliance evaluation, facility auditing and employee training to monitor
operational activities and to prevent conditions that might threaten the
environment.
In 1998, the Corporation published its first Environmental, Health and
Safety Report. The report includes the Corporation's environmental policy and
summarizes environmental performance and emissions data for 1997. The
Corporation's Executive Committee approved an environmental business plan in
July 1998 and implementation of the plan has begun. As part of the plan, the
Corporation will develop an integrated environmental management system. The
Corporation's objective is to ensure that its activities are conducted in an
environmentally responsible and consistent manner.
The Corporation expects continuing expenditures for environmental
assessment and remediation. Sites where corrective action may be necessary
include gasoline stations, terminals, refineries (including solid waste
management units under permits issued pursuant to the Resource Conservation and
Recovery Act) and, although not significant, Superfund sites where the
Corporation has been named a potentially responsible party under the Superfund
legislation. The Corporation expects that existing reserves for environmental
liabilities will adequately cover costs of assessing and remediating known
sites.
The Corporation expended $9 million in 1998, $12 million in 1997 and $13
million in 1996 for remediation. In addition, capital expenditures for
facilities, primarily to comply with federal, state and local environmental
standards, were $4 million in 1998, $5 million in 1997 and $7 million in 1996.
- --------------------------------------------------------------------------------
25
- --------------------------------------------------------------------------------
<PAGE> 21
- --------------------------------------------------------------------------------
FORWARD LOOKING INFORMATION
Certain sections of the Financial Review, including references to the
Corporation's future results of operations and financial position, capital
expenditures, planned asset sales, derivative disclosures and year 2000 and
environmental sections, represent forward looking information. The disclosures
are based on the Corporation's current understanding and assessment of these
activities and reasonable assumptions about the future. Actual results may
differ from these disclosures because of changes in market conditions,
government actions and other factors.
DIVIDENDS
Cash dividends on common stock totaled $.60 per share ($.15 per quarter)
during 1998 and 1997.
STOCK MARKET INFORMATION
The common stock of Amerada Hess Corporation is traded principally on the New
York Stock Exchange (ticker symbol: AHC). High and low sales prices in 1998 and
1997 were as follows:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------
1998 1997
------------------ ------------------
QUARTER ENDED HIGH LOW HIGH LOW
- ---------------------------------------------------------------------
<S> <C> <C> <C> <C>
March 31 61 1/16 48 5/16 62 52 3/8
June 30 59 1/8 50 5/16 56 3/8 47 3/8
September 30 59 5/8 46 62 3/4 54 3/16
December 31 59 1/8 48 64 1/2 49 5/16
=====================================================================
</TABLE>
QUARTERLY FINANCIAL DATA
Quarterly results of operations for the years ended December 31, 1998 and 1997
follow (millions of dollars, except per share data):
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------
INCOME NET
SALES (LOSS) INCOME
AND OTHER EXCLUDING NET (LOSS)
OPERATING GROSS SPECIAL SPECIAL INCOME PER SHARE
QUARTER REVENUES PROFIT(a) ITEMS ITEMS (LOSS) (DILUTED)
- -------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
1998
First $1,826 $ 253 $ (69) $ 56(b) $ (13) $ (.14)
Second 1,617 259 (22) -- (22) (.24)
Third 1,531 239 (6) -- (6) (.07)
Fourth 1,616 158 (99) (319)(c) (418) (4.70)
- ---------------------------------------------------------------------
Total $6,590 $ 909 $ (196) $ (263) $ (459)
=====================================================================
1997
First $2,397 $ 336 $ 4 $ -- $ 4 $ .05
Second 1,834 312 31 11(b) 42 .45
Third 1,885 342 23 -- 23 .25
Fourth 2,118 270 (44) (17)(d) (61) (.67)
- ---------------------------------------------------------------------
Total $8,234 $1,260 $ 14 $ (6) $ 8
=====================================================================
</TABLE>
(a) Gross profit represents sales and other operating revenues less cost of
products sold and operating expenses and depreciation, depletion and
amortization.
(b) Represents net gains on asset sales.
(c) Includes a loss of $106 million on the formation of a refining joint
venture, impairment of assets and operating leases of $198 million and
accrued severance costs of $15 million.
(d) Reflects an after-tax charge of $55 million for the impairment of two oil
fields in the United Kingdom North Sea and income of $38 million from a
refund of United Kingdom taxes.
The results of operations for the periods reported herein should not be
considered as indicative of future operating results.
- --------------------------------------------------------------------------------
26
- --------------------------------------------------------------------------------
<PAGE> 22
STATEMENT OF CONSOLIDATED INCOME
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------------------------------
FOR THE YEARS ENDED DECEMBER 31
----------------------------------------------------
THOUSANDS OF DOLLARS, EXCEPT PER SHARE DATA 1998 1997 1996
- ---------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
REVENUES
Sales (excluding excise taxes) and
other operating revenues $6,590,009 $8,233,723 $8,272,186
Non-operating revenues
Gain (loss) on asset sales (25,679) 16,463 529,271
Equity in loss of HOVENSA L.L.C (15,848) -- --
Other 68,984 89,860 128,254
- ---------------------------------------------------------------------------------------------------------------------------------
Total revenues 6,617,466 8,340,046 8,929,711
- ---------------------------------------------------------------------------------------------------------------------------------
COSTS AND EXPENSES
Cost of products sold and operating expenses 5,024,405 6,301,046 6,074,695
Exploration expenses, including dry holes and
lease impairment 337,518 373,180 342,860
Selling, general and administrative expenses 753,251 649,815 602,329
Interest expense 152,934 136,149 165,501
Depreciation, depletion and amortization 656,991 672,669 730,382
Impairment of assets and operating leases 206,478 80,602 --
- ---------------------------------------------------------------------------------------------------------------------------------
Total costs and expenses 7,131,577 8,213,461 7,915,767
- ---------------------------------------------------------------------------------------------------------------------------------
Income (loss) before income taxes (514,111) 126,585 1,013,944
Provision (benefit) for income taxes (55,218) 119,085 353,845
- ---------------------------------------------------------------------------------------------------------------------------------
NET INCOME (LOSS) $ (458,893) $ 7,500 $ 660,099
=================================================================================================================================
NET INCOME (LOSS) PER SHARE
Basic $(5.12) $.08 $7.13
Diluted $(5.12) $.08 $7.09
=================================================================================================================================
</TABLE>
STATEMENT OF CONSOLIDATED RETAINED EARNINGS
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------------------------------
FOR THE YEARS ENDED DECEMBER 31
-------------------------------------------------------
THOUSANDS OF DOLLARS, EXCEPT PER SHARE DATA 1998 1997 1996
- ---------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
BALANCE AT BEGINNING OF YEAR $2,463,005 $2,613,920 $2,017,064
Net income (loss) (458,893) 7,500 660,099
Dividends declared--common stock
($.60 per share in 1998, 1997 and 1996) (54,520) (55,090) (55,761)
Common stock acquired and retired (45,526) (103,325) (7,482)
- ---------------------------------------------------------------------------------------------------------------------------------
BALANCE AT END OF YEAR $1,904,066 $2,463,005 $2,613,920
=================================================================================================================================
</TABLE>
See accompanying notes to consolidated financial statements.
27
<PAGE> 23
CONSOLIDATED BALANCE SHEET
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------------------------------
AT DECEMBER 31
-----------------------------
THOUSANDS OF DOLLARS 1998 1997
- ---------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C>
ASSETS
CURRENT ASSETS
Cash and cash equivalents $ 73,791 $ 91,154
Accounts receivable
Trade 954,353 951,796
Other 58,831 41,302
Inventories 482,182 937,949
Current portion of deferred income taxes 114,194 105,391
Other current assets 203,355 76,040
- ---------------------------------------------------------------------------------------------------------------------------------
Total current assets 1,886,706 2,203,632
- ---------------------------------------------------------------------------------------------------------------------------------
INVESTMENTS AND ADVANCES
HOVENSA L.L.C 702,581 --
Other 232,826 250,458
- ---------------------------------------------------------------------------------------------------------------------------------
Total investments and advances 935,407 250,458
- ---------------------------------------------------------------------------------------------------------------------------------
PROPERTY, PLANT AND EQUIPMENT
Exploration and production 9,718,424 8,779,807
Refining 73,244 2,688,403
Marketing 1,120,109 1,025,178
Shipping 115,462 128,247
- ---------------------------------------------------------------------------------------------------------------------------------
Total--at cost 11,027,239 12,621,635
Less reserves for depreciation, depletion, amortization and lease impairment 6,835,301 7,430,841
- ---------------------------------------------------------------------------------------------------------------------------------
Property, plant and equipment--net 4,191,938 5,190,794
- ---------------------------------------------------------------------------------------------------------------------------------
NOTE RECEIVABLE 538,500 --
- ---------------------------------------------------------------------------------------------------------------------------------
DEFERRED INCOME TAXES AND OTHER ASSETS 330,432 289,735
- ---------------------------------------------------------------------------------------------------------------------------------
TOTAL ASSETS $7,882,983 $7,934,619
=================================================================================================================================
</TABLE>
28
<PAGE> 24
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------------------------------------------------------------
AT DECEMBER 31
-----------------------------------
1998 1997
- -----------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C>
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts payable--trade $ 713,831 $ 752,576
Accrued liabilities 554,632 491,644
Deferred revenue 251,328 175,684
Taxes payable 100,686 195,692
Notes payable 3,500 17,825
Current maturities of long-term debt 172,820 106,430
- -----------------------------------------------------------------------------------------------------------------------------------
Total current liabilities 1,796,797 1,739,851
- -----------------------------------------------------------------------------------------------------------------------------------
LONG-TERM DEBT 2,476,145 2,003,033
- -----------------------------------------------------------------------------------------------------------------------------------
DEFERRED LIABILITIES AND CREDITS
Deferred income taxes 483,843 562,371
Other 482,786 413,665
- -----------------------------------------------------------------------------------------------------------------------------------
Total deferred liabilities and credits 966,629 976,036
- -----------------------------------------------------------------------------------------------------------------------------------
STOCKHOLDERS' EQUITY
Preferred stock, par value $1.00
Authorized--20,000,000 shares for issuance in series -- --
Common stock, par value $1.00
Authorized--200,000,000 shares
Issued--90,356,705 shares in 1998; 91,451,205 shares in 1997 90,357 91,451
Capital in excess of par value 764,412 774,631
Retained earnings 1,904,066 2,463,005
Equity adjustment from foreign currency translation (115,423) (113,388)
- -----------------------------------------------------------------------------------------------------------------------------------
Total stockholders' equity 2,643,412 3,215,699
- -----------------------------------------------------------------------------------------------------------------------------------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY $ 7,882,983 $ 7,934,619
===================================================================================================================================
</TABLE>
The consolidated financial statements reflect the successful efforts method of
accounting for oil and gas exploration and producing activities.
See accompanying notes to consolidated financial statements.
29
<PAGE> 25
STATEMENT OF CONSOLIDATED CASH FLOWS
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------------------------
FOR THE YEARS ENDED DECEMBER 31
--------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997 1996
- -----------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss) $ (458,893) $ 7,500 $ 660,099
Adjustments to reconcile net income (loss) to net cash
provided by operating activities
Depreciation, depletion and amortization 656,991 672,669 730,382
Impairment of assets and operating leases 206,478 80,602 --
Exploratory dry hole costs 159,435 191,351 164,601
Lease impairment 47,440 37,185 52,825
(Gain) loss on asset sales 25,679 (16,463) (529,271)
(Increase) decrease in accounts receivable 6,335 (148,488) (66,452)
(Increase) decrease in inventories 122,204 333,477 (434,206)
Increase in accounts payable, accrued liabilities and
deferred revenue 185,403 198,596 110,736
Increase (decrease) in taxes payable (87,118) (46,626) 32,623
Provision (benefit) for deferred income taxes (137,922) (80,208) 43,483
Changes in prepaid expenses and other (207,244) 20,412 42,901
- -----------------------------------------------------------------------------------------------------------------------------------
Net cash provided by operating activities 518,788 1,250,007 807,721
- -----------------------------------------------------------------------------------------------------------------------------------
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures
Exploration and production (1,306,438) (1,157,938) (788,286)
Refining, marketing and shipping (132,240) (187,652) (72,339)
- -----------------------------------------------------------------------------------------------------------------------------------
Total capital expenditures (1,438,678) (1,345,590) (860,625)
Proceeds from asset sales and other 502,854 63,017 1,037,073
- -----------------------------------------------------------------------------------------------------------------------------------
Net cash provided by (used in) investing activities (935,824) (1,282,573) 176,448
- -----------------------------------------------------------------------------------------------------------------------------------
CASH FLOWS FROM FINANCING ACTIVITIES
Issuance (repayment) of notes (14,342) 1,982 (72,046)
Long-term borrowings 848,320 398,391 --
Repayment of long-term debt and capitalized
lease obligations (317,144) (209,000) (794,527)
Cash dividends paid (54,647) (55,373) (55,746)
Common stock acquired (59,167) (122,283) (8,236)
- -----------------------------------------------------------------------------------------------------------------------------------
Net cash provided by (used in) financing activities 403,020 13,717 (930,555)
- -----------------------------------------------------------------------------------------------------------------------------------
EFFECT OF EXCHANGE RATE CHANGES ON CASH (3,347) (2,519) 2,837
- -----------------------------------------------------------------------------------------------------------------------------------
NET INCREASE (DECREASE) IN CASH AND
CASH EQUIVALENTS (17,363) (21,368) 56,451
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 91,154 112,522 56,071
- -----------------------------------------------------------------------------------------------------------------------------------
CASH AND CASH EQUIVALENTS AT END OF YEAR $ 73,791 $ 91,154 $ 112,522
===================================================================================================================================
</TABLE>
See accompanying notes to consolidated financial statements.
30
<PAGE> 26
STATEMENT OF CONSOLIDATED CHANGES IN COMMON STOCK AND CAPITAL IN EXCESS OF PAR
VALUE
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------------------------
COMMON STOCK
------------------------
CAPITAL IN
NUMBER OF EXCESS OF
THOUSANDS OF DOLLARS SHARES AMOUNT PAR VALUE
- -------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
BALANCE AT JANUARY 1, 1996 93,011,255 $ 93,011 $ 744,252
Distributions to trustee under executive incentive
compensation and stock ownership plans (net) 211,750 212 11,300
Common stock acquired and retired (154,700) (155) (1,247)
Employee stock options exercised 5,000 5 254
- -------------------------------------------------------------------------------------------------
BALANCE AT DECEMBER 31, 1996 93,073,305 93,073 754,559
Distributions to trustee under executive incentive
compensation and stock ownership plans (net) 719,000 719 38,145
Common stock acquired and retired (2,368,100) (2,368) (19,419)
Employee stock options exercised 27,000 27 1,346
- -------------------------------------------------------------------------------------------------
BALANCE AT DECEMBER 31, 1997 91,451,205 91,451 774,631
Cancellations under executive incentive
compensation and stock ownership plans (net) (26,000) (26) (1,292)
Common stock acquired and retired (1,071,500) (1,071) (9,073)
Employee stock options exercised 3,000 3 146
- -------------------------------------------------------------------------------------------------
BALANCE AT DECEMBER 31, 1998 90,356,705 $ 90,357 $ 764,412
=================================================================================================
</TABLE>
STATEMENT OF CONSOLIDATED COMPREHENSIVE INCOME
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------------------------
FOR THE YEARS ENDED DECEMBER 31
------------------------------------------
THOUSANDS OF DOLLARS 1998 1997 1996
- -------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
COMPONENTS OF COMPREHENSIVE INCOME (LOSS)
Net income (loss) $(458,893) $ 7,500 $ 660,099
Change in foreign currency translation adjustment (2,035) (35,467) 116,010
- -------------------------------------------------------------------------------------------------
COMPREHENSIVE INCOME (LOSS) $(460,928) $ (27,967) $ 776,109
=================================================================================================
</TABLE>
See accompanying notes to consolidated financial statements.
31
<PAGE> 27
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
- --------------------------------------------------------------------------------
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
NATURE OF BUSINESS: Amerada Hess Corporation and subsidiaries (the
"Corporation") engage in the exploration for and the production, purchase,
transportation and sale of crude oil and natural gas. These activities are
conducted primarily in the United States, United Kingdom, Norway and Gabon. The
Corporation also has oil and gas activities in Azerbaijan, Denmark, Indonesia,
Thailand and other countries. In addition, the Corporation manufactures,
purchases, transports and markets refined petroleum and other energy products.
The Corporation owns 50% of a refinery joint venture in the United States Virgin
Islands. An additional refining facility, terminals and retail outlets are
located principally on the East Coast of the United States.
In preparing financial statements, management makes estimates and
assumptions that affect the reported amounts of assets and liabilities in the
balance sheet and revenues and expenses in the income statement. Actual results
could differ from those estimates. Among the estimates made by management are:
oil and gas reserves, inventory and other asset valuations, pension liabilities,
environmental obligations, depreciation, depletion and amortization,
dismantlement costs and income taxes.
PRINCIPLES OF CONSOLIDATION: The consolidated financial statements include
the accounts of Amerada Hess Corporation and subsidiaries. The Corporation's
interests in oil and gas exploration and production ventures are proportionately
consolidated.
Investments in affiliated companies, 20% to 50% owned, including HOVENSA
L.L.C., the Corporation's refining joint venture, are stated at cost of
acquisition plus the Corporation's equity in undistributed net income since
acquisition. The change in the equity in net income of these companies is
included in non-operating revenues in the income statement.
Intercompany transactions and accounts are eliminated in consolidation.
Certain amounts in prior years' financial statements have been reclassified
to conform with current year presentation.
CASH AND CASH EQUIVALENTS: Cash equivalents consist of highly liquid
investments, which are readily convertible into cash and have maturities of
three months or less.
INVENTORIES: Crude oil and refined product inventories are valued at the
lower of cost or market value. Cost is determined principally on the average
cost method.
Inventories of materials and supplies are valued at or below cost.
EXPLORATION AND DEVELOPMENT COSTS: Oil and gas exploration and production
activities are accounted for on the successful efforts method. Costs of
acquiring undeveloped oil and gas leasehold acreage, including lease bonuses,
brokers' fees and other related costs, are capitalized. Provisions for
impairment of undeveloped oil and gas leases are based on periodic evaluations
and other factors.
Annual lease rentals and exploration expenses, including geological and
geophysical expenses and exploratory dry hole costs, are charged against income
as incurred.
Costs of drilling and equipping productive wells, including development dry
holes, and related production facilities are capitalized.
DEPRECIATION, DEPLETION AND AMORTIZATION: Depreciation, depletion and
amortization of oil and gas production equipment, properties and wells are
determined on the unit-of-production method based on estimated recoverable oil
and gas reserves. Depreciation of all other plant and equipment is determined on
the straight-line method based on estimated useful lives.
The estimated costs of dismantlement, restoration and abandonment, less
estimated salvage values, of offshore oil and gas production platforms and
certain other facilities are taken into account in determining depreciation.
RETIREMENT OF PROPERTY, PLANT AND EQUIPMENT: Costs of property, plant and
equipment retired or otherwise disposed of, less accumulated reserves, are
reflected in net income.
MAINTENANCE AND REPAIRS: The estimated costs of major maintenance, including
turnarounds at the Port Reading refining facility, are accrued. Other
expenditures for maintenance and repairs are charged against income as incurred.
Renewals and improvements are treated as additions to property, plant and
equipment, and items replaced are treated as retirements.
- --------------------------------------------------------------------------------
32
- --------------------------------------------------------------------------------
<PAGE> 28
- --------------------------------------------------------------------------------
ENVIRONMENTAL EXPENDITURES: The Corporation capitalizes environmental
expenditures that increase the life or efficiency of property or that reduce or
prevent environmental contamination. The Corporation accrues for environmental
expenses resulting from existing conditions related to past operations when the
costs are probable and reasonably estimable.
EMPLOYEE STOCK OPTIONS AND NONVESTED COMMON STOCK AWARDS: The Corporation uses
the intrinsic value method to account for employee stock options. Because the
exercise prices of employee stock options equal or exceed the market price of
the stock on the date of grant, the Corporation does not recognize compensation
expense. The Corporation records compensation expense for nonvested common stock
awards ratably over the vesting period.
FOREIGN CURRENCY TRANSLATION: The local currency is the functional currency
(primary currency in which business is conducted) for the Corporation's United
Kingdom and Norwegian operations. The U.S. dollar is the functional currency for
other foreign operations. Adjustments resulting from translating foreign
functional currency assets and liabilities into U.S. dollars are recorded in a
separate component of stockholders' equity entitled "Equity adjustment from
foreign currency translation." Gains or losses resulting from transactions in
other than the functional currency are reflected in net income. The Corporation
is studying a change to the U.S. dollar functional currency for its United
Kingdom operations for 1999 reporting.
HEDGING: The Corporation uses futures, forwards, options and swaps to hedge the
effects of fluctuations in the prices of crude oil, natural gas and refined
products and changes in interest rates and foreign currency values. These
transactions meet the requirements for hedge accounting, including designation
and correlation. The resulting gains or losses, measured by quoted market
prices, termination values or other methods, are accounted for as part of the
transactions being hedged, except that losses not expected to be recovered upon
the completion of hedged transactions are expensed. On the balance sheet,
deferred gains and losses are included in current assets and liabilities.
TRADING: The results of commodity trading activities are marked to market, with
gains and losses recorded in operating revenue.
2. REFINING JOINT VENTURE
On October 30, 1998, the Corporation formed a joint venture with Petroleos de
Venezuela, S.A. (PDVSA). Pursuant to this transaction, PDVSA, V.I., Inc. (PDVSA
V.I.), a wholly-owned subsidiary of PDVSA, purchased a 50% interest in the fixed
assets of the Corporation's Virgin Islands refinery for $62,500,000 in cash, a
10-year note from PDVSA V.I. for $562,500,000, bearing interest at 8.46% per
annum and requiring principal payments over its term, and a $125,000,000,
10-year, contingent note, also bearing interest at 8.46% per annum (which
contingent note was not valued for accounting purposes). PDVSA V.I.'s payment
obligations under both notes are guaranteed by PDVSA and secured by a pledge of
PDVSA V.I.'s interest in the joint venture. The Corporation's Virgin Islands
subsidiary and PDVSA V.I. each contributed their 50% interest in the refinery
fixed assets to HOVENSA L.L.C. (HOVENSA). HOVENSA is 50% owned by this
subsidiary of the Corporation and 50% owned by PDVSA V.I. and operates the
Virgin Islands refinery. The Corporation purchased refined products from HOVENSA
at a cost of approximately $151,000,000 during the two months ended December 31,
1998.
At closing, the Corporation also received $307,000,000 from HOVENSA as
payment for the net working capital of the refinery. The Corporation's
investment in the joint venture is accounted for using the equity method.
Summarized financial information for HOVENSA as of December 31, 1998 and for the
two months since inception follows:
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------
Thousands of dollars 1998
- ---------------------------------------------------------------------------
<S> <C>
SUMMARIZED BALANCE SHEET INFORMATION
At December 31
Current assets $ 352,171
Net fixed assets 1,343,712
Other assets 27,711
Current liabilities (133,454)
Long-term debt (250,000)
Deferred liabilities and credits (27,718)
- ---------------------------------------------------------------------------
Partners' equity $ 1,312,422
- ---------------------------------------------------------------------------
SUMMARIZED INCOME STATEMENT INFORMATION
For the period ended December 31
Total revenues $ 344,896
Costs and expenses (343,904)
Inventory market value changes (31,999)
- ---------------------------------------------------------------------------
Net loss $ (31,007)*
===========================================================================
</TABLE>
* The Corporation's share of HOVENSA's loss was $15,848.
- --------------------------------------------------------------------------------
33
- --------------------------------------------------------------------------------
<PAGE> 29
- --------------------------------------------------------------------------------
3. SPECIAL ITEMS
1998: In connection with the sale of a 50% interest in the fixed assets of the
Corporation's Virgin Islands refinery, the Corporation recorded a loss of
$106,000,000. The contingent note of $125,000,000 received from PDVSA V.I. was
not valued for accounting purposes. The Corporation also recorded an additional
noncash charge of $44,000,000 for the reduction in carrying value of its crude
oil storage terminal in St. Lucia, which will be used less as a result of the
joint venture. The amount of this charge was based on an estimate of fair value
of the facility determined by discounting anticipated future net cash flows. No
income tax benefit was recorded on either charge.
Exploration and production results included a special after-tax charge of
$77,000,000 for the reduction in market value of fixed-priced drilling service
contracts due to the decline in worldwide crude oil prices. This charge reflects
estimated costs that will not be recovered through subcontracts on several
drilling rigs. Pre-tax excess costs of approximately $90,000,000 were recorded
as liabilities in the balance sheet. A charge of $54,000,000 ($35,000,000 after
income taxes) was also recorded for the impairment of capitalized costs related
to a North Sea oil discovery, which is uneconomic at current prices. The
Corporation also expensed $29,000,000 for its share of asset impairment of an
equity affiliate and $13,000,000 for the reduction in carrying value of
developed and undeveloped properties in the United States and United Kingdom.
Net expenses of approximately $15,000,000 were also recorded for severance
covering approximately 400 exploration and production employees (of which
approximately 200 had been terminated at year-end). Approximately $2,000,000 of
severance has been paid in 1998. In addition, the Corporation recorded gains of
$56,200,000 on the sale of oil and gas assets in the United States and Norway.
The impairment of carrying values of the crude oil storage terminal and
exploration and production assets, including the loss on drilling service
contracts, is reflected in a separate impairment line in the income statement.
Gains (losses) on asset sales and equity in net income (loss) of affiliates are
included in non-operating revenues. Severance and related costs, before income
tax effect, are included in selling, general and administrative expenses.
1997: The Corporation recorded a charge of $80,600,000 (approximately
$55,000,000 after income taxes) for impairment of long-lived assets and a
long-term operating lease, as a result of reserve revisions on two oil fields in
the United Kingdom North Sea. The Corporation also recorded income of
$38,200,000 from a refund of United Kingdom Petroleum Revenue Taxes. In 1997,
the Corporation also sold its interest in a United States natural gas field
resulting in an after-tax gain of $10,700,000.
1996: The Corporation sold exploration and production assets in 1996
resulting in a net gain of $421,150,000. These sales included the Corporation's
Canadian operations, certain United States and United Kingdom producing
properties and Abu Dhabi assets.
4. ACCOUNTING CHANGES
On January 1, 1998, the Corporation began capitalizing the cost of internal use
software in accordance with AICPA Statement of Position 98-1, Accounting for the
Costs of Computer Software Developed or Obtained for Internal Use. This
accounting change increased net income for the year by $13,867,000 ($.15 per
share).
Effective January 1, 1999, the Corporation adopted the last-in, first-out
(LIFO) method of accounting for its refining and marketing inventory.
In June 1998, the Financial Accounting Standards Board issued FAS No. 133,
Accounting for Derivative Instruments and Hedging Activities. The Corporation
must adopt this statement by January 1, 2000. The Corporation has not yet
determined the effect of FAS No. 133 on its earnings and financial position.
5. INVENTORIES
Inventories at December 31 are as follows:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997
- -----------------------------------------------------------------------------
<S> <C> <C>
Crude oil and other charge stocks $ 35,818 $269,783
Refined and other finished products 386,917 564,973
- -----------------------------------------------------------------------------
422,735 834,756
Materials and supplies 59,447 103,193
- -----------------------------------------------------------------------------
Total $482,182* $937,949
=============================================================================
</TABLE>
* Excludes inventories of 50% owned refinery joint venture, HOVENSA L.L.C.,
accounted for using the equity method.
- --------------------------------------------------------------------------------
34
- --------------------------------------------------------------------------------
<PAGE> 30
- --------------------------------------------------------------------------------
6. SHORT-TERM NOTES AND RELATED LINES OF CREDIT
Short-term notes payable to banks amounted to $3,500,000 at December 31, 1998
and $17,825,000 at December 31, 1997. The weighted average interest rates on
these borrowings were 8.8% and 7.0% at December 31, 1998 and 1997, respectively.
At December 31, 1998, the Corporation has uncommitted arrangements with banks
for unused lines of credit aggregating $362,000,000. No compensating balances or
fees are required for these lines of credit. In addition, the Corporation has an
unused committed short-term credit line of $300,000,000 with facility fees of
.10% maturing in August 1999.
7. LONG-TERM DEBT
Long-term debt at December 31 consists of the following:
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997
- -------------------------------------------------------------------------
<S> <C> <C>
6.1% Marine Terminal Revenue
Bonds--Series 1994--
City of Valdez, Alaska,
due 2024 $ 20,000 $ 20,000
Pollution Control Revenue Bonds,
weighted average rate 6.6%,
due through 2022 52,607 52,590
Fixed rate notes, payable principally
to insurance companies,
weighted average rate 8.1%,
due through 2014 1,154,285 1,013,376
Global Revolving Credit Facility
with banks, weighted average
rate 6.1%*, due 2002 1,195,000 968,000
Project lease financing, weighted
average rate 5.1%, due
through 2014 185,513 --
Capitalized lease obligations,
weighted average rate 6.7%, due
through 2010 35,960 49,497
Other loans, weighted average rate
8.2%, due through 2007 5,600 6,000
- -------------------------------------------------------------------------
2,648,965 2,109,463
Less amount included in
current maturities 172,820 106,430
- -------------------------------------------------------------------------
Total $2,476,145 $2,003,033
=========================================================================
</TABLE>
* Includes effect of interest rate conversion agreements.
The aggregate long-term debt maturing during the next five years is as
follows (in thousands): 1999--$172,820 (included in current liabilities);
2000--$4,923; 2001--$25,409; 2002--$1,395,693 and 2003--$80,986.
The Corporation's long-term debt agreements contain various restrictions
and conditions, including working capital requirements and limitations on total
borrowings and cash dividends. At December 31, 1998, the Corporation meets the
required working capital ratio of 1 to 1. The Corporation has additional
borrowing capacity of $1,313,000,000 for the construction or acquisition of
assets and $213,000,000 of retained earnings free of dividend restrictions.
The Corporation has a $2,000,000,000 Global Revolving Credit Facility (the
"Facility"), of which $1,195,000,000 is outstanding at December 31, 1998.
Outstanding amounts are due to be repaid in 2002, but may be extended for an
additional two years with the consent of the lenders. Borrowings bear interest
at a margin above the London Interbank Offered Rate ("LIBOR") based on the
Corporation's capitalization ratio. The current borrowing rate is .20% above
LIBOR. Facility fees of .125% per annum are payable on the amount of the credit
line.
During 1998, the Corporation entered into the sale and leaseback of its
interests in the production platforms and related facilities of two Gulf of
Mexico producing properties. These transactions have been accounted for as
financings. At December 31, the outstanding obligations amount to $185,513,000,
maturing through 2014.
The Corporation sold a portion of its subsequent year crude oil production
in 1998 and 1997 and used the proceeds to repay revolving credit debt.
Accordingly, at December 31, 1998 and 1997, $249,325,000 and $173,681,000,
respectively, are included in deferred revenue on the balance sheet.
At December 31, 1998, the Corporation has interest rate conversion
agreements, accounted for by the accrual method, that effectively convert
floating rate debt to fixed rate debt, reducing the percentage of its floating
rate debt from 47% to 32%.
In 1998 and 1997, the Corporation capitalized interest of $23,559,000 and
$10,284,000 on major development projects. The total amount of interest paid
(net of amounts capitalized), principally on short-term and long-term debt, in
1998, 1997 and 1996 was $154,419,000, $146,795,000 and $176,033,000,
respectively.
- --------------------------------------------------------------------------------
35
- --------------------------------------------------------------------------------
<PAGE> 31
- --------------------------------------------------------------------------------
8. STOCKHOLDERS' EQUITY
The Corporation has outstanding stock options and nonvested common stock under
its 1995 Long-Term Incentive Plan and its Executive Long-Term Incentive
Compensation and Stock Ownership Plan (which expired in 1997). Generally, stock
options vest one year from the date of grant and the exercise price equals or
exceeds the market price on the date of grant. Nonvested common stock vests
three or five years from the date of grant, depending on the terms of the award.
The Corporation's stock option activity in 1998, 1997 and 1996 consisted of
the following:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
WEIGHTED-
AVERAGE
OPTIONS EXERCISE PRICE
(THOUSANDS) PER SHARE
- -----------------------------------------------------------------------------
<S> <C> <C>
Granted in 1995, approved in 1996 863 $56.39
Granted in 1996 629 62.22
Exercised (5) 51.75
Forfeited (66) 56.39
- -----------------------------------------------------------------------------
Outstanding at December 31, 1996 1,421 58.99
Granted 873 54.75
Exercised (27) 50.86
Forfeited (19) 59.52
- -----------------------------------------------------------------------------
Outstanding at December 31, 1997 2,248 57.43
Granted 873 53.05
Exercised (3) 49.75
Forfeited (23) 56.22
- -----------------------------------------------------------------------------
Outstanding at December 31, 1998 3,095 $56.21
=============================================================================
Exercisable at December 31, 1996 792 $56.42
Exercisable at December 31, 1997 1,376 59.14
Exercisable at December 31, 1998 2,230 57.44
=============================================================================
</TABLE>
Exercise prices for employee stock options at December 31, 1998 ranged from
$49.00 to $64.75 per share. The weighted-average remaining contractual life of
employee stock options is 8.3 years.
The Corporation uses the Black-Scholes model to estimate the fair value of
employee stock options for pro forma disclosure of the effects on net income and
earnings per share. The Corporation used the following weighted-average
assumptions in the Black-Scholes model for 1998, 1997 and 1996, respectively:
risk-free interest rates of 5.6%, 5.9% and 5.8%; expected stock price volatility
of .218, .220 and .213; a dividend yield of 1.1%; and an expected life of seven
years. The Corporation's net income would have been reduced by approximately
$19,100,000 in 1998, $7,600,000 in 1997 and $7,700,000 in 1996 ($.21 per share
in 1998 and $.08 per share in 1997 and 1996, diluted) if option expense were
recorded using the fair value method.
The weighted-average fair values of options granted for which the exercise
price equaled the market price on the date of grant were $17.50 in 1998, $18.69
in 1997 and $18.91 in 1996. In 1996, the fair value of options granted for which
the exercise price exceeded the market price on the date of grant was $15.47.
Total compensation expense for nonvested common stock was $15,975,000 in
1998, $11,553,000 in 1997 and $5,915,000 in 1996. Awards of nonvested common
stock were as follows:
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------
SHARES OF
NONVESTED WEIGHTED-
COMMON STOCK AVERAGE
AWARDED PRICE ON DATE
(THOUSANDS) OF GRANT
- --------------------------------------------------------------------------
<S> <C> <C>
Granted in 1995, approved in 1996 203 $49.81
Granted in 1996 95 57.30
Granted in 1997 746 53.94
Granted in 1998 18 53.08
==========================================================================
</TABLE>
At December 31, 1998, the number of common shares reserved for issuance is
as follows:
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------
<S> <C>
1995 Long-Term Incentive Plan
Future awards 621,000
Stock options outstanding 3,094,500
Stock appreciation rights 52,000
Warrants* 1,051,584
- --------------------------------------------------------------------------
Total 4,819,084
==========================================================================
</TABLE>
* Issued in connection with an insurance company financing, exercisable
through June 27, 2001 at $64.66 per share.
9. FOREIGN CURRENCY TRANSLATION
Foreign currency exchange transactions reflected in net income (after income tax
effect) amounted to gains of $2,511,000 in 1998, $5,073,000 in 1997 and
$1,813,000 in 1996.
- --------------------------------------------------------------------------------
36
- --------------------------------------------------------------------------------
<PAGE> 32
- --------------------------------------------------------------------------------
10. PENSION PLANS
The Corporation has defined benefit pension plans for substantially all of its
employees. The following table reconciles the benefit obligation and fair value
of plan assets and discloses the funded status:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997
- ----------------------------------------------------------------------------
<S> <C> <C>
Reconciliation of pension benefit obligation
Benefit obligation at January 1 $ 464,728 $ 419,798
Service cost 19,280 17,751
Interest cost 32,841 31,565
Actuarial loss 48,855 18,273
Benefit payments (23,000) (22,659)
- ----------------------------------------------------------------------------
Pension benefit obligation at
December 31 542,704 464,728
- ----------------------------------------------------------------------------
Reconciliation of fair value of plan assets
Fair value of plan assets at January 1 427,912 381,532
Actual return on plan assets 54,311 60,216
Employer contributions 16,833 8,204
Employee contributions 793 619
Benefit payments (23,000) (22,659)
- ----------------------------------------------------------------------------
Fair value of plan assets at
December 31 476,849 427,912
- ----------------------------------------------------------------------------
Funded status at December 31
Funded status (65,855) (36,816)
Unrecognized prior service cost 11,166 10,321
Unrecognized (gain) loss 736 (27,193)
- ----------------------------------------------------------------------------
Accrued pension liability $ (53,953) $ (53,688)
============================================================================
</TABLE>
The pension information shown above, which indicates a pension benefit
obligation in excess of plan assets of $65,855,000, is based on Financial
Accounting Standard No. 87, Employer's Accounting for Pensions. This standard
requires using a current discount rate at which the pension obligation could be
effectively settled. The rate is based on the rates of return of high-quality,
fixed-income investments. In determining the funding requirements of U.S.
pension plans in accordance with income tax regulations, the expected long-term
rate of return on the pension funds' investments is used as the discount rate.
This rate has historically been higher than the discount rate required by FAS
87, because pension assets are invested in equity and fixed income securities.
Had the long-term rate of return been used to discount the pension benefit
obligation, the present value of the Corporation's pension liability at December
31, 1998 would have been reduced by approximately $100,000,000. Accordingly, the
Corporation and its actuaries believe that its pension plans are adequately
funded. The Corporation's United States pension plan also meets the full funding
requirements under income tax regulations.
Pension expense consisted of the following:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997 1996
- ----------------------------------------------------------------------------
<S> <C> <C> <C>
Service cost $ 19,280 $ 19,109 $ 17,915
Interest cost 32,841 33,162 29,961
Expected return on
plan assets (36,221) (32,390) (29,128)
Amortization of
transition obligation (72) (3,052) (3,064)
Amortization of prior
service cost 1,280 1,280 568
Amortization of net gain (22) (1,692) (778)
- ----------------------------------------------------------------------------
Pension expense $ 17,086 $ 16,417 $ 15,474
============================================================================
</TABLE>
Prior service costs and gains and losses in excess of 10% of the greater of
the benefit obligation and the market value of assets are amortized over the
average remaining service period of active employees.
The weighted-average actuarial assumptions used by the Corporation's
pension plans at December 31 were as follows:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------------------
1998 1997
- ----------------------------------------------------------------------------
<S> <C> <C>
Discount rate 6.4% 7.0%
Expected long-term rate of return on
plan assets 8.3% 8.5%
Rate of compensation increases 4.9% 5.1%
============================================================================
</TABLE>
The Corporation also has a nonqualified supplemental pension plan covering
certain employees. The supplemental pension plan provides for incremental
pension payments from the Corporation's funds so that total pension payments
equal amounts that would have been payable from the Corporation's principal
pension plan were it not for limitations imposed by income tax regulations. The
benefit obligation related to this unfunded plan totaled $41,802,000 at December
31, 1998 and $35,606,000 at December 31, 1997. Pension expense for the plan was
$6,271,000 in 1998, $5,098,000 in 1997 and $3,970,000 in 1996. At December 31,
1998, the Corporation has accrued $25,205,000 for this plan. The trust
established to fund the supplemental plan held assets valued at $6,209,000 at
December 31, 1998.
- --------------------------------------------------------------------------------
37
- --------------------------------------------------------------------------------
<PAGE> 33
- --------------------------------------------------------------------------------
11. PROVISION FOR INCOME TAXES
The provision (benefit) for income taxes consisted of:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997 1996
- -----------------------------------------------------------------------------
<S> <C> <C> <C>
United States Federal
Current $ 9,510 $ 16,210 $ 20,156
Deferred (68,203) (27,254) 6,528
State 1,702 1,418 4,904
- -----------------------------------------------------------------------------
(56,991) (9,626) 31,588
- -----------------------------------------------------------------------------
Foreign
Current 71,492 181,665* 285,302
Deferred (66,310) (41,599) 36,955
- -----------------------------------------------------------------------------
5,182 140,066 322,257
- -----------------------------------------------------------------------------
Adjustment of deferred tax
liability for foreign
income tax rate change (3,409) (11,355) --
- -----------------------------------------------------------------------------
Total $ (55,218) $ 119,085 $ 353,845
=============================================================================
</TABLE>
* Includes income tax refund of $38,180.
Income (loss) before income taxes consisted of the following:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997 1996
- -----------------------------------------------------------------------------
<S> <C> <C> <C>
United States $ (205,522) $ 3,533 $ 55,678
Foreign* (308,589) 123,052 958,266
- -----------------------------------------------------------------------------
Total $ (514,111) $ 126,585 $1,013,944
=============================================================================
</TABLE>
* Foreign income includes the Corporation's Virgin Islands, shipping and
other operations located outside of the United States.
Deferred income taxes arise from temporary differences between the tax
basis of assets and liabilities and their reported amounts in the financial
statements. A summary of the components of deferred tax liabilities and assets
at December 31 follows:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997
- ----------------------------------------------------------------------------
<S> <C> <C>
Deferred tax liabilities
Fixed assets and investments $ 272,461 $ 390,214
Foreign petroleum taxes 238,568 294,004
Other 58,251 51,778
- ----------------------------------------------------------------------------
Total deferred tax liabilities 569,280 735,996
- -----------------------------------------------------------------------------
Deferred tax assets
Accrued liabilities 194,109 170,730
Net operating and capital loss
carryforwards 224,765 471,583
Tax credit carryforwards 126,590 132,014
Other 41,592 41,826
- ----------------------------------------------------------------------------
Total deferred tax assets 587,056 816,153
Valuation allowance (141,113) (330,119)
- ----------------------------------------------------------------------------
Net deferred tax assets 445,943 486,034
- -----------------------------------------------------------------------------
Net deferred tax liabilities $ 123,337 $ 249,962
============================================================================
</TABLE>
The difference between the Corporation's effective income tax rate and the
United States statutory rate is reconciled below:
- ---------------------------------------------------------------------------
1998 1997 1996
- ---------------------------------------------------------------------------
United States statutory rate (35.0)% 35.0% 35.0%
Effect of foreign operations,
including foreign tax credits 24.2 72.3 (.6)
Effect of capital and other
loss carryforwards (.2) (8.3) .5
State income taxes, net of
Federal income tax benefit .2 .7 .3
Prior year adjustments (.3) (3.5) (.1)
Tax credits -- (.8) (.1)
Other .4 (1.3) (.1)
- ---------------------------------------------------------------------------
Total (10.7)% 94.1% 34.9%
===========================================================================
The Corporation has not recorded deferred income taxes applicable to
undistributed earnings of foreign subsidiaries that are indefinitely reinvested
in foreign operations. Undistributed earnings amounted to approximately $750
million at December 31, 1998, excluding amounts which, if remitted, generally
would not result in any additional U.S. income taxes because of available
foreign tax credits. If the earnings of such foreign subsidiaries were not
indefinitely reinvested, a deferred tax liability of approximately $140 million
would have been required.
- --------------------------------------------------------------------------------
38
- --------------------------------------------------------------------------------
<PAGE> 34
- --------------------------------------------------------------------------------
For income tax reporting at December 31, 1998, the Corporation has general
business credit carryforwards of approximately $27 million, principally expiring
in 1999 through 2001. In addition, the Corporation has alternative minimum tax
credit carryforwards of approximately $100 million, which can be carried forward
indefinitely. A net operating loss carryforward of approximately $1.1 billion is
also available to offset income of the HOVENSA joint venture partners.
Income taxes paid (net of refunds) in 1998, 1997 and 1996 amounted to
$140,470,000, $259,767,000 and $294,905,000, respectively.
12. NET INCOME PER SHARE
The weighted average number of common shares used in the basic and diluted
earnings per share computations are summarized below:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
THOUSANDS OF SHARES 1998 1997 1996
- -----------------------------------------------------------------------------
<S> <C> <C> <C>
Common shares--basic 89,585 91,254 92,552
Effect of dilutive securities
Nonvested common stock -- 428 539
Stock options -- 51 19
- -----------------------------------------------------------------------------
Common shares--diluted 89,585 91,733 93,110
=============================================================================
</TABLE>
Diluted common shares include shares that would be outstanding assuming the
fulfillment of restrictions on nonvested shares and the exercise of stock
options. In 1998, the above table excludes the antidilutive effect of 666,000
nonvested common shares and 78,000 stock options. The table also excludes the
effect of out-of-the-money options on 1,626,000 shares, 867,000 shares and
336,000 shares in 1998, 1997 and 1996, respectively.
13. FINANCIAL INSTRUMENTS, HEDGING AND TRADING ACTIVITIES
The Corporation uses futures, forwards, options and swaps, individually or
in combination, to reduce the effects of fluctuations in crude oil, natural gas
and refined product prices and in fixed-price sales contracts. In addition, the
Corporation uses interest-rate conversion agreements to fix the interest rates
on a portion of its long-term, floating-rate debt. Foreign currency contracts
are used to protect the Corporation from fluctuations in exchange rates.
COMMODITY HEDGING: At December 31, 1998, the Corporation's hedging activities
included commodity and financial contracts, maturing mainly in 1999, covering
3,000,000 net barrels of crude oil and refined products (12,700,000 net barrels
in 1997) and 4,500,000 net Mcf of natural gas (9,300,000 net Mcf in 1997). In
1998, the crude oil and refined product hedges related to refining and marketing
operations. In 1997, the crude oil and refined product hedges included 7,300,000
barrels related to exploration and production activities, and the remainder
related to refining and marketing operations.
The Corporation produced 75,000,000 barrels of crude oil and natural gas
liquids and 210,000,000 Mcf of natural gas in 1998, and had approximately
22,000,000 barrels of crude oil and refined products in its refining and
marketing inventories at December 31, 1998. Since the contracts described above
are designated as hedges and correlate to price movements of crude oil, natural
gas and refined products, any gains or losses resulting from market changes will
be offset by losses or gains on the Corporation's hedged inventory or
production. Net deferred gains from the Corporation's hedging activities were
$5,000,000 at December 31, 1998, including $2,000,000 of unrealized gains
($22,000,000 at December 31, 1997, including $17,000,000 of unrealized gains).
The Corporation also had a net loss on certain contracts and offsetting
fixed-price sales commitments of approximately $1,700,000 in 1998 and a net gain
of $600,000 in 1997.
FINANCIAL INSTRUMENTS: At December 31, 1998, the Corporation has $400,000,000 in
interest-rate conversion agreements outstanding ($300,000,000 at December 31,
1997). The Corporation has $97,200,000 of notional value foreign currency
forward and purchased option contracts maturing generally in 1999 ($179,200,000
at December 31, 1997) and $137,900,000 in letters of credit outstanding
($66,100,000 at December 31, 1997). Notional amounts do not quantify risk or
represent
- --------------------------------------------------------------------------------
39
- --------------------------------------------------------------------------------
<PAGE> 35
- --------------------------------------------------------------------------------
assets or liabilities of the Corporation, but are used in the calculation of
cash settlements under the contracts.
FAIR VALUE DISCLOSURE: The carrying amounts of cash and cash equivalents,
short-term debt and long-term, variable-rate debt approximate fair value. The
Corporation estimates the fair value of its long-term, fixed-rate debt generally
using discounted cash flow analysis based on the Corporation's current borrowing
rates for debt with similar maturities. Interest-rate conversion agreements and
foreign currency exchange contracts are valued based on current termination
values or quoted market prices of comparable contracts. The Corporation's
valuation of commodity contracts considers quoted market prices, time value,
volatility of the underlying commodities and other factors.
The carrying amounts of the Corporation's financial instruments and
commodity contracts, including those used in the Corporation's hedging and
trading activities, generally approximate their fair values at December 31,
1998, except as follows:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
1998 1997
------------------- --------------------
BALANCE BALANCE
MILLIONS OF DOLLARS, SHEET FAIR SHEET FAIR
ASSET (LIABILITY) AMOUNT VALUE AMOUNT VALUE
- ----------------------------------------------------------------------------
<S> <C> <C> <C> <C>
Long-term, fixed-rate
debt $(1,418) $(1,477) $(1,091) $(1,194)
Interest rate conversion
agreements -- (24) -- (4)
Foreign currency
exchange agreements
and options -- 2 -- 4
============================================================================
</TABLE>
MARKET AND CREDIT RISKS: The Corporation's financial instruments expose it to
market and credit risks and may at times be concentrated with certain
counterparties or groups of counterparties. Counterparties to the Corporation's
financial instruments are major financial institutions and their credit
worthiness is subject to continuing review and full performance is anticipated.
COMMODITY TRADING: The Corporation, including a consolidated partnership formed
in 1997, trades energy commodities, including futures, forwards, options and
swaps, based on expectations of future market conditions. The Corporation's
results from trading activities, including its share of the earnings of the
trading partnership, amounted to a net loss of approximately $26,000,000 in 1998
and net income of approximately $4,000,000 in 1997.
The following table presents the year-end fair values of energy commodities
and derivative instruments used in trading activities and the average aggregate
fair values during the year:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
FAIR VALUE
--------------------------------------------
AT AVERAGE AT AVERAGE
MILLIONS OF DOLLARS, DEC. 31, FOR DEC. 31, FOR
ASSET (LIABILITY) 1998 1998 1997 1997
- ----------------------------------------------------------------------------
<S> <C> <C> <C> <C>
Commodities $ 98 $ 75 $ 33 $ 21
Futures and forwards
Assets 29 43 20 13
Liabilities (29) (39) (14) (9)
Options
Held (7) (3) (4) (2)
Written 8 5 6 1
Swaps
Assets 110 59 3 4
Liabilities (117) (60) (1) (1)
============================================================================
</TABLE>
Notional amounts of commodities and derivatives relating to trading
activities follow:
- -----------------------------------------------------------------------------
AT DECEMBER 31,
------------------
MILLIONS OF BARRELS OF OIL EQUIVALENT 1998 1997
- ----------------------------------------------------------------------------
Commodities 7 2
Futures and forwards--Long 39 26
--Short (51) (28)
Options--Held 20 8
--Written (21) (10)
Swaps*--Held 83 7
--Written (81) (9)
============================================================================
* Includes 18 million barrels long and 20 million barrels short related to
basis swaps at December 31, 1998 (4 million barrels long and 6 million
barrels short in 1997).
- --------------------------------------------------------------------------------
40
- --------------------------------------------------------------------------------
<PAGE> 36
- --------------------------------------------------------------------------------
14. LEASED ASSETS
The Corporation and certain of its subsidiaries lease floating production
systems, drilling rigs, tankers, gasoline stations, office space and other
assets for varying periods. At December 31, 1998, the Corporation had net
capital lease assets of $75,971,000, representing natural gas production and
transportation facilities in the United Kingdom, which are included in property,
plant and equipment in the balance sheet.
At December 31, 1998, future minimum rental payments applicable to capital
and noncancelable operating leases with remaining terms of one year or more
(other than oil and gas leases) are as follows:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
OPERATING CAPITAL
THOUSANDS OF DOLLARS LEASES LEASES
- -----------------------------------------------------------------------------
<S> <C> <C>
1999 $ 339,672 $28,632
2000 323,195 1,149
2001 130,987 1,149
2002 104,072 1,149
2003 88,634 1,149
Remaining years 367,248 6,896
- -----------------------------------------------------------------------------
Total minimum lease payments 1,353,808 40,124
Less: Imputed interest -- 4,164
Income from subleases 28,228 --
- -----------------------------------------------------------------------------
Net minimum lease payments $1,325,580* $35,960
=============================================================================
Capitalized lease obligations--
Current $28,004
Long-term 7,956
- -----------------------------------------------------------------------------
Total $35,960
=============================================================================
</TABLE>
* Of the total future minimum payments under operating leases, $156,126 has
been accrued at December 31, 1998.
Rental expense for all operating leases, other than rentals applicable to
oil and gas leases, was as follows:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
THOUSANDS OF DOLLARS 1998 1997 1996
- -----------------------------------------------------------------------------
<S> <C> <C> <C>
Total rental expense $178,560 $195,246 $185,669
Less income from subleases 29,979 11,792 5,264
- -----------------------------------------------------------------------------
Net rental expense $148,581 $183,454 $180,405
=============================================================================
</TABLE>
15. SEGMENT INFORMATION
The Corporation adopted FAS No. 131, Disclosures about Segments of an Enterprise
and Related Information, during the fourth quarter of 1998. FAS No. 131 requires
financial information by geographic area and operating segment.
Financial information by major geographic area for each of the three years
ended December 31, 1998 follows:
<TABLE>
<CAPTION>
- -----------------------------------------------------------------------------
UNITED CONSOLI-
MILLIONS OF DOLLARS STATES* EUROPE OTHER DATED
- -----------------------------------------------------------------------------
<S> <C> <C> <C> <C>
1998
Operating revenues $5,051 $1,479 $ 60 $6,590
Property, plant and
equipment (net) 1,457 2,351 384 4,192
=============================================================================
1997
Operating revenues $6,557 $1,619 $ 58 $8,234
Property, plant and
equipment (net) 2,872 2,106 213 5,191
=============================================================================
1996
Operating revenues $6,589 $1,568 $115 $8,272
Property, plant and
equipment (net) 2,671 2,020 216 4,907
=============================================================================
</TABLE>
* Includes U.S. Virgin Islands and shipping operations.
The Corporation operates principally in the petroleum industry and its
operating segments are (1) exploration and production and (2) refining,
marketing and shipping. Exploration and production operations include the
exploration for and the production, purchase, gathering, transportation and sale
of crude oil and natural gas. Refining, marketing and shipping operations
include the manufacture, purchase, transportation, and marketing of petroleum
and other energy products.
- --------------------------------------------------------------------------------
41
- --------------------------------------------------------------------------------
<PAGE> 37
- --------------------------------------------------------------------------------
15. SEGMENT INFORMATION (CONTINUED)
The following table presents financial data by major operating segment for each
of the three years ended December 31, 1998:
<TABLE>
<CAPTION>
- ----------------------------------------------------------------------------------------------------------------------------
EXPLORATION REFINING,
AND MARKETING
MILLIONS OF DOLLARS PRODUCTION AND SHIPPING CORPORATE CONSOLIDATED*
- ----------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
1998
Operating revenues
Total operating revenues $1,985 $4,722 $ 1
Less: Transfers between affiliates 118 -- --
- ----------------------------------------------------------------------------------------------------------------------------
Operating revenues from unaffiliated customers $1,867 $4,722 $ 1 $6,590
============================================================================================================================
Operating profit (loss) $ (29) $ (54) $ (37) $ (120)
Earnings of equity affiliates 7 (13) 5 (1)
Interest income 11 11 1 23
Interest expense -- -- (153) (153)
(Provision) benefit for income taxes (7) 38 24 55
- ----------------------------------------------------------------------------------------------------------------------------
Income (loss) before special items (18) (18) (160) (196)
Special items (113) (150) -- (263)
- ----------------------------------------------------------------------------------------------------------------------------
Net income (loss) $ (131) $ (168) $(160) $ (459)
============================================================================================================================
Depreciation, depletion, amortization and lease impairment $ 577 $ 125 $ 2 $ 704
Investments in equity affiliates 96 781 56 933
Identifiable assets 4,286 3,126 471 7,883
Capital employed 3,231 2,065 -- 5,296
Capital expenditures 1,307 129 3 1,439
============================================================================================================================
1997
Operating revenues
Total operating revenues $3,091 $5,285 $ 1
Less: Transfers between affiliates 142 1 --
- ----------------------------------------------------------------------------------------------------------------------------
Operating revenues from unaffiliated customers $2,949 $5,284 $ 1 $8,234
============================================================================================================================
Operating profit (loss) $ 387 $ (119) $ (49) $ 219
Earnings of equity affiliates 21 6 5 32
Interest income 14 3 1 18
Interest expense -- -- (136) (136)
(Provision) benefit for income taxes (164) -- 45 (119)
- ----------------------------------------------------------------------------------------------------------------------------
Income (loss) before special items 258 (110) (134) 14
Special items (6) -- -- (6)
- ----------------------------------------------------------------------------------------------------------------------------
Net income (loss) $ 252 $ (110) $(134) $ 8
============================================================================================================================
Depreciation, depletion, amortization and lease impairment $ 553 $ 118 $ 2 $ 673
Investments in equity affiliates 114 77 53 244
Identifiable assets 3,727 3,713 495 7,935
Capital employed 2,468 2,875 -- 5,343
Capital expenditures 1,158 183 5 1,346
============================================================================================================================
1996
Operating revenues
Total operating revenues $3,166 $5,283 $ 2
Less: Transfers between affiliates 177 1 1
- ----------------------------------------------------------------------------------------------------------------------------
Operating revenues from unaffiliated customers $2,989 $5,282 $ 1 $8,272
============================================================================================================================
Operating profit (loss) $ 608 $ 163 $ (51) $ 720
Earnings of equity affiliates 13 9 3 25
Interest income 7 2 2 11
Interest expense -- -- (166) (166)
(Provision) benefit for income taxes (418) 7 57 (354)
- ----------------------------------------------------------------------------------------------------------------------------
Income (loss) before special items 210 181 (155) 236
Special items 424 -- -- 424
- ----------------------------------------------------------------------------------------------------------------------------
Net income (loss) $ 634 $ 181 $(155) $ 660
============================================================================================================================
Depreciation, depletion, amortization and lease impairment $ 603 $ 125 $ 2 $ 730
Investments in equity affiliates 92 71 50 213
Identifiable assets 3,600 3,802 382 7,784
Capital employed 2,156 3,167 -- 5,323
Capital expenditures 788 68 5 861
============================================================================================================================
</TABLE>
* After elimination of transactions between affiliates, which are valued at
approximate market prices.
42
<PAGE> 38
REPORT OF MANAGEMENT
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
- --------------------------------------------------------------------------------
The consolidated financial statements of Amerada Hess Corporation and
consolidated subsidiaries were prepared by and are the responsibility of
management. These financial statements conform with generally accepted
accounting principles and are, in part, based on estimates and judgements of
management. Other information included in this Annual Report is consistent with
that in the consolidated financial statements.
The Corporation maintains a system of internal controls designed to provide
reasonable assurance that assets are safeguarded and that transactions are
properly executed and recorded. Judgements are required to balance the relative
costs and benefits of this system of internal controls.
The Corporation's consolidated financial statements have been audited by
Ernst & Young LLP, independent auditors, who have been selected by the Audit
Committee of the Board of Directors and approved by the stockholders. Ernst &
Young LLP assesses the Corporation's system of internal controls and performs
tests and procedures that they consider necessary to arrive at an opinion on the
fairness of the consolidated financial statements.
The Audit Committee of the Board of Directors, which consists solely of
nonemployee directors, meets periodically with the independent auditors,
internal auditors and management to review and discuss the Corporation's
financial information, the system of internal controls and the results of
internal and external audits. Ernst & Young LLP and the Corporation's internal
auditors have unrestricted access to the Audit Committee to discuss audit
findings and other financial matters.
/s/ John B. Hess
John B. Hess
Chairman of the Board and Chief Executive Officer
/s/ John Y. Schreyer
John Y. Schreyer
Executive Vice President and Chief Financial Officer
- --------------------------------------------------------------------------------
43
- --------------------------------------------------------------------------------
<PAGE> 39
REPORT OF ERNST & YOUNG LLP, INDEPENDENT AUDITORS
- --------------------------------------------------------------------------------
The Board of Directors and Stockholders
Amerada Hess Corporation
We have audited the accompanying consolidated balance sheet of Amerada Hess
Corporation and consolidated subsidiaries as of December 31, 1998 and 1997 and
the related consolidated statements of income, retained earnings, changes in
common stock and capital in excess of par value, cash flows and comprehensive
income for each of the three years in the period ended December 31, 1998. These
financial statements are the responsibility of the Corporation'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 consolidated financial position of Amerada Hess
Corporation and consolidated subsidiaries at December 31, 1998 and 1997 and the
consolidated results of their operations and their consolidated cash flows for
each of the three years in the period ended December 31, 1998, in conformity
with generally accepted accounting principles.
As discussed in Note 4 to the consolidated financial statements, in 1998
the Corporation adopted AICPA Statement of Position 98-1, Accounting for the
Costs of Computer Software Developed or Obtained for Internal Use.
/s/ Ernst & Young LLP
- ---------------------
Ernst & Young LLP
New York, NY
February 22, 1999
- --------------------------------------------------------------------------------
44
- --------------------------------------------------------------------------------
<PAGE> 40
SUPPLEMENTARY OIL AND GAS DATA
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
- --------------------------------------------------------------------------------
The supplementary oil and gas data that follows is presented in accordance with
Statement of Financial Accounting Standards (FAS) No. 69, Disclosures about Oil
and Gas Producing Activities, and includes (1) costs incurred, capitalized costs
and results of operations relating to oil and gas producing activities, (2) net
proved oil and gas reserves, and (3) a standardized measure of discounted future
net cash flows relating to proved oil and gas reserves, including a
reconciliation of changes therein.
The Corporation produces crude oil and natural gas in the United States,
Europe, Gabon, Indonesia and Azerbaijan. Exploration and/or development
activities are also conducted, or are planned, in Thailand, Kazakstan, Brazil
and in certain other countries.
During 1996, the Corporation sold its Canadian and Abu Dhabi operations and
certain United States and United Kingdom producing properties. In the geographic
data which follows, information on Canada and Abu Dhabi has been combined for
disclosure purposes.
COSTS INCURRED IN OIL AND GAS PRODUCING ACTIVITIES
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------------------------
UNITED AFRICA, ASIA CANADA AND
FOR THE YEARS ENDED DECEMBER 31 (MILLIONS OF DOLLARS) TOTAL STATES EUROPE AND OTHER ABU DHABI
- ---------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
1998
Property acquisitions $203 $ 41 $ 7 $155 $ --
Exploration 319 106 145 68 --
Development 915 182 650 83 --
- ---------------------------------------------------------------------------------------------------------------------------
1997
Property acquisitions $237 $ 39 $193 $ 5 $ --
Exploration 383 131 215 37 --
Development 679 231 408 40 --
- ---------------------------------------------------------------------------------------------------------------------------
1996
Property acquisitions $ 70 $ 32 $ 1 $ 37 $ --
Exploration 332 135 160 22 15
Development 512 152 337 12 11
===========================================================================================================================
</TABLE>
CAPITALIZED COSTS RELATING TO OIL AND GAS PRODUCING ACTIVITIES
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------------------------
AT DECEMBER 31 (MILLIONS OF DOLLARS) 1998 1997
- ---------------------------------------------------------------------------------------------------------------------------
<S> <C> <C>
Unproved properties $ 434 $ 449
Proved properties 1,596 1,425
Wells, equipment and related facilities 7,688 6,906
- ---------------------------------------------------------------------------------------------------------------------------
Total costs 9,718 8,780
Less: Reserve for depreciation, depletion, amortization and lease impairment 6,131 5,687
- ---------------------------------------------------------------------------------------------------------------------------
Net capitalized costs $3,587 $3,093
===========================================================================================================================
</TABLE>
45
<PAGE> 41
- --------------------------------------------------------------------------------
The results of operations for oil and gas producing activities shown below
exclude sales of purchased crude oil and natural gas, non-operating revenues
(including gains on sales of oil and gas properties), interest expense and gains
and losses resulting from foreign currency exchange transactions. Therefore,
these results differ from the net income from exploration and production
operations in Note 15 to the financial statements.
RESULTS OF OPERATIONS FOR OIL AND GAS PRODUCING ACTIVITIES
<TABLE>
<CAPTION>
- --------------------------------------------------------------------------------------------------------------------------------
AFRICA, CANADA
UNITED ASIA AND AND
FOR THE YEARS ENDED DECEMBER 31 (MILLIONS OF DOLLARS) TOTAL STATES EUROPE OTHER ABU DHABI
- --------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
1998
Sales and other operating revenues
Unaffiliated customers $1,355 $344 $ 975 $ 36 $--
Inter-company 144 84 -- 60 --
- --------------------------------------------------------------------------------------------------------------------------------
Total revenues 1,499 428 975 96 --
- --------------------------------------------------------------------------------------------------------------------------------
Costs and expenses
Production expenses, including related taxes 463 129 317 17 --
Exploration expenses, including dry holes and lease impairment 338 127 146 65 --
Other operating expenses 226* 72 103 51 --
Depreciation, depletion and amortization 528 155 345 28 --
Impairment of assets and operating leases 162 7 104 51 --
- --------------------------------------------------------------------------------------------------------------------------------
Total costs and expenses 1,717 490 1,015 212 --
- --------------------------------------------------------------------------------------------------------------------------------
Results of operations before income taxes (218) (62) (40) (116) --
Provision (benefit) for income taxes (38) (22) (22) 6 --
- --------------------------------------------------------------------------------------------------------------------------------
Results of operations $ (180) $(40) $ (18) $(122) $--
================================================================================================================================
1997
Sales and other operating revenues
Unaffiliated customers $1,983 $496 $1,454 $ 33 $--
Inter-company 134 76 -- 58 --
- --------------------------------------------------------------------------------------------------------------------------------
Total revenues 2,117 572 1,454 91 --
- --------------------------------------------------------------------------------------------------------------------------------
Costs and expenses
Production expenses, including related taxes 557 157 390 10 --
Exploration expenses, including dry holes and lease impairment 373 145 187 41 --
Other operating expenses 186 58 94 34 --
Depreciation, depletion and amortization 552 126 408 18 --
Impairment of assets and operating leases 81 -- 81 -- --
- --------------------------------------------------------------------------------------------------------------------------------
Total costs and expenses 1,749 486 1,160 103 --
- --------------------------------------------------------------------------------------------------------------------------------
Results of operations before income taxes 368 86 294 (12) --
Provision for income taxes 143 30 107 6 --
- --------------------------------------------------------------------------------------------------------------------------------
Results of operations $ 225 $ 56 $ 187 $ (18) $--
================================================================================================================================
1996
Sales and other operating revenues
Unaffiliated customers $2,034 $474 $1,473 $ 11 $76
Inter-company 184 102 -- 78 4
- --------------------------------------------------------------------------------------------------------------------------------
Total revenues 2,218 576 1,473 89 80
- --------------------------------------------------------------------------------------------------------------------------------
Costs and expenses
Production expenses, including related taxes 619 182 410 7 20
Exploration expenses, including dry holes and lease impairment 343 183 124 27 9
Other operating expenses 203 66 105 23 9
Depreciation, depletion and amortization 603 165 405 16 17
- --------------------------------------------------------------------------------------------------------------------------------
Total costs and expenses 1,768 596 1,044 73 55
- --------------------------------------------------------------------------------------------------------------------------------
Results of operations before income taxes 450 (20) 429 16 25
Provision (benefit) for income taxes 266 (6) 276 (4) --
- --------------------------------------------------------------------------------------------------------------------------------
Results of operations $ 184 $(14) $ 153 $ 20 $25
================================================================================================================================
</TABLE>
* Includes severance and related costs of approximately $32 million.
46
<PAGE> 42
- --------------------------------------------------------------------------------
The Corporation's net oil and gas reserves have been estimated by DeGolyer
and MacNaughton, independent consultants. The reserves in the tabulation below
include proved undeveloped crude oil and natural gas reserves that will require
substantial future development expenditures. The estimates of the Corporation's
proved reserves of crude oil and natural gas (after deducting royalties and
operating interests owned by others) follow:
OIL AND GAS RESERVES
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------------------------------------------------------
UNITED AFRICA, ASIA CANADA AND
TOTAL STATES EUROPE AND OTHER ABU DHABI
- -------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C>
NET PROVED DEVELOPED AND UNDEVELOPED RESERVES
CRUDE OIL, INCLUDING CONDENSATE AND NATURAL
GAS LIQUIDS (MILLIONS OF BARRELS)
At January 1, 1996 695 205 412 18 60
Revisions of previous estimates 13 6 2 5 --
Improved recovery 6 6 -- -- --
Extensions, discoveries and other additions 45 5 40 -- --
Purchases of minerals in-place 4 -- -- 4 --
Sales of minerals in-place (98) (33) (8) -- (57)
Production (87) (18) (63) (3) (3)
- ----------------------------------------------------------------------------------------------------------------------------
At December 31, 1996 578 171 383 24 --
Revisions of previous estimates 47 7 40 -- --
Extensions, discoveries and other additions 39 12 21 6 --
Purchases of minerals in-place 14 1 13 -- --
Sales of minerals in-place (3) (1) (2) -- --
Production (80) (16) (60) (4) --
- ----------------------------------------------------------------------------------------------------------------------------
At December 31, 1997 595 174 395 26 --
Revisions of previous estimates 80 6 72 2 --
Extensions, discoveries and other additions 55 6 22 27 --
Purchases of minerals in-place 45 -- 2 43 --
Sales of minerals in-place (5) -- (5) -- --
Production (75) (17) (52) (6) --
- ----------------------------------------------------------------------------------------------------------------------------
At December 31, 1998 695 169 434 92 --
============================================================================================================================
NATURAL GAS (MILLIONS OF MCF)
At January 1, 1996 2,481 1,038 927 53 463
Revisions of previous estimates 108 34 74 -- --
Improved recovery 3 3 -- -- --
Extensions, discoveries and other additions 84 50 34 -- --
Purchases of minerals in-place 39 4 -- 35 --
Sales of minerals in-place (598) (158) -- -- (440)
Production (251) (124) (104) -- (23)
- ----------------------------------------------------------------------------------------------------------------------------
At December 31, 1996 1,866 847 931 88 --
Revisions of previous estimates 78 16 54 8 --
Extensions, discoveries and other additions 195 68 48 79 --
Purchases of minerals in-place 44 -- 44 -- --
Sales of minerals in-place (41) (8) (33) -- --
Production (207) (114) (93) -- --
- ----------------------------------------------------------------------------------------------------------------------------
At December 31, 1997 1,935 809 951 175 --
Revisions of previous estimates 147 35 113 (1) --
Extensions, discoveries and other additions 227 80 54 93 --
Purchases of minerals in-place 3 1 2 -- --
Sales of minerals in-place (47) (38) (9) -- --
Production (210) (107) (102) (1) --
- ----------------------------------------------------------------------------------------------------------------------------
At December 31, 1998 2,055 780* 1,009 266 --
============================================================================================================================
NET PROVED DEVELOPED RESERVES
CRUDE OIL, INCLUDING CONDENSATE AND NATURAL
GAS LIQUIDS (MILLIONS OF BARRELS)
At January 1, 1996 540 157 310 13 60
At December 31, 1996 412 121 280 11 --
At December 31, 1997 420 123 280 17 --
At December 31, 1998 452 132 293 27 --
NATURAL GAS (MILLIONS OF MCF)
At January 1, 1996 2,036 755 823 -- 458
At December 31, 1996 1,368 553 815 -- --
At December 31, 1997 1,342 497 796 49 --
At December 31, 1998 1,330 525 753 52 --
============================================================================================================================
</TABLE>
* Excludes 483 million Mcf of carbon dioxide gas for sale or use in company
operations.
47
<PAGE> 43
- --------------------------------------------------------------------------------
The standardized measure of discounted future net cash flows relating to
proved oil and gas reserves required to be disclosed by FAS No. 69 is based on
assumptions and judgements. As a result, the future net cash flow estimates are
highly subjective and could be materially different if other assumptions were
used. Therefore, caution should be exercised in the use of the data presented
below.
Future net cash flows are calculated by applying year-end oil and gas
selling prices (adjusted for price changes provided by contractual arrangements,
including hedges) to estimated future production of proved oil and gas reserves,
less estimated future development and production costs and future income tax
expenses. Future net cash flows are discounted at the prescribed rate of 10%. No
recognition is given in the discounted future net cash flow estimates to
depreciation, depletion, amortization and lease impairment, exploration
expenses, interest expense, general and administrative expenses and changes in
future prices and costs. The selling prices of crude oil and natural gas have
decreased significantly during 1998 and are highly volatile.
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
RELATING TO PROVED OIL AND GAS RESERVES
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------------------
UNITED AFRICA, ASIA
AT DECEMBER 31 (MILLIONS OF DOLLARS) TOTAL STATES EUROPE AND OTHER
- ------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
1998
Future revenues $10,826 $2,866 $ 6,457 $1,503
- ------------------------------------------------------------------------------------------------------------------------------
Less:
Future development and production costs 6,412 1,479 4,183 750
Future income tax expenses 1,411 374 795 242
- ------------------------------------------------------------------------------------------------------------------------------
7,823 1,853 4,978 992
- ------------------------------------------------------------------------------------------------------------------------------
Future net cash flows 3,003 1,013 1,479 511
Less: Discount at 10% annual rate 980 403 326 251
- ------------------------------------------------------------------------------------------------------------------------------
Standardized measure of discounted future
net cash flows $ 2,023 $ 610 $ 1,153 $ 260
==============================================================================================================================
1997
Future revenues $13,001 $4,078 $ 8,207 $ 716
- ------------------------------------------------------------------------------------------------------------------------------
Less:
Future development and production costs 6,033 1,533 4,243 257
Future income tax expenses 3,127 831 2,073 223
- ------------------------------------------------------------------------------------------------------------------------------
9,160 2,364 6,316 480
- ------------------------------------------------------------------------------------------------------------------------------
Future net cash flows 3,841 1,714 1,891 236
Less: Discount at 10% annual rate 1,424 692 648 84
- ------------------------------------------------------------------------------------------------------------------------------
Standardized measure of discounted future
net cash flows $ 2,417 $1,022 $ 1,243 $ 152
==============================================================================================================================
1996
Future revenues $18,479 $5,936 $11,630 $ 913
- ------------------------------------------------------------------------------------------------------------------------------
Less:
Future development and production costs 6,551 1,906 4,382 263
Future income tax expenses 5,297 1,319 3,632 346
- ------------------------------------------------------------------------------------------------------------------------------
11,848 3,225 8,014 609
- ------------------------------------------------------------------------------------------------------------------------------
Future net cash flows 6,631 2,711 3,616 304
Less: Discount at 10% annual rate 2,447 1,160 1,213 74
- ------------------------------------------------------------------------------------------------------------------------------
Standardized measure of discounted future
net cash flows $ 4,184 $1,551 $ 2,403 $ 230
==============================================================================================================================
</TABLE>
48
<PAGE> 44
- --------------------------------------------------------------------------------
CHANGES IN STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET
CASH FLOWS RELATING TO PROVED OIL AND GAS RESERVES
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------------------------
FOR THE YEARS ENDED DECEMBER 31 (MILLIONS OF DOLLARS) 1998 1997 1996
- ------------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
Standardized measure of discounted future net cash flows at beginning of year $ 2,417 $ 4,184 $ 3,758
- ------------------------------------------------------------------------------------------------------------------------------------
Changes during the year
Sales and transfers of oil and gas produced during year, net of
production costs (1,036) (1,558) (1,603)
Development costs incurred during year 915 679 512
Net changes in prices and production costs applicable to future production (2,215) (3,304) 2,577
Net change in estimated future development costs (273) (392) (168)
Extensions and discoveries (including improved recovery) of oil and
gas reserves, less related costs 220 140 315
Revisions of previous oil and gas reserve estimates 233 271 311
Purchases (sales) of minerals in-place, net 126 90 (983)
Accretion of discount 435 769 600
Net change in income taxes 1,036 1,355 (814)
Revision in rate or timing of future production and other changes 165 183 (321)
- ------------------------------------------------------------------------------------------------------------------------------------
Total (394) (1,767) 426
- ------------------------------------------------------------------------------------------------------------------------------------
Standardized measure of discounted future net cash flows at end of year $ 2,023 $ 2,417 $ 4,184
====================================================================================================================================
</TABLE>
49
<PAGE> 45
TEN-YEAR SUMMARY OF FINANCIAL DATA
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------------------------
THOUSANDS OF DOLLARS, EXCEPT PER SHARE DATA 1998 1997 1996
- ------------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
STATEMENT OF CONSOLIDATED INCOME
Revenues
Sales (excluding excise taxes) and other operating revenues
Crude oil (including sales of purchased oil) $ 893,921 $ 1,435,848 $ 1,528,692
Natural gas (including sales of purchased gas) 1,710,743 1,414,314 1,364,833
Petroleum products 3,464,229 4,960,986 5,080,790
Other operating revenues 521,116 422,575 297,871
- ------------------------------------------------------------------------------------------------------------------------------------
Total 6,590,009 8,233,723 8,272,186
Non-operating revenues (including asset sales) 27,457 106,323 657,525(b)
- ------------------------------------------------------------------------------------------------------------------------------------
Total revenues 6,617,466 8,340,046 8,929,711
- ------------------------------------------------------------------------------------------------------------------------------------
Costs and expenses
Cost of products sold and operating expenses 5,024,405 6,301,046 6,074,695
Exploration expenses, including dry holes
and lease impairment 337,518 373,180 342,860
Selling, general and administrative expenses 753,251 649,815 602,329
Interest expense 152,934 136,149 165,501
Depreciation, depletion and amortization 656,991 672,669 730,382
Asset impairment 206,478 80,602 --
- ------------------------------------------------------------------------------------------------------------------------------------
Total costs and expenses 7,131,577 8,213,461 7,915,767
- ------------------------------------------------------------------------------------------------------------------------------------
Income (loss) before income taxes (514,111) 126,585 1,013,944
Provision (benefit) for income taxes (55,218) 119,085 353,845
- ------------------------------------------------------------------------------------------------------------------------------------
Net income (loss) $ (458,893)(a) $ 7,500 $ 660,099
====================================================================================================================================
Net income (loss) per share
Basic $ (5.12) $ .08 $ 7.13
Diluted (5.12) .08 7.09
====================================================================================================================================
DIVIDENDS PER SHARE OF COMMON STOCK $ .60 $ .60 $ .60
WEIGHTED AVERAGE NUMBER OF
SHARES OUTSTANDING (DILUTED)--in thousands 89,585 91,733 93,110
====================================================================================================================================
</TABLE>
(a) Includes after-tax special charges aggregating $262,800 ($2.93 per share)
representing impairments of assets and operating leases, a net loss on
asset sales and accrued severance.
(b) Includes a pre-tax gain on asset sales of $529,271. The net gain, after
applicable income taxes, was $421,150 ($4.52 per share).
(c) Reflects a charge for impairment of long-lived assets on adoption of FAS
No. 121. The net effect, after income taxes, was $415,542 ($4.47 per
share).
See accompanying notes to consolidated financial statements.
50
<PAGE> 46
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------------------------------------------------
1995 1994 1993 1992 1991 1990 1989
- -------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
$ 1,565,310 $ 1,228,045 $ 1,219,750 $ 1,362,118 $ 1,448,793 $ 1,248,193 $ 904,233
1,120,450 1,063,560 1,020,563 787,996 574,004 458,615 315,578
4,311,082 3,980,563 3,348,900 3,428,702 3,897,748 4,587,646 4,107,770
305,465 329,816 290,308 279,541 346,300 653,051 261,373
- -------------------------------------------------------------------------------------------------------------------------
7,302,307 6,601,984 5,879,521 5,858,357 6,266,845 6,947,505 5,588,954
222,482 96,809 21,153 95,352 149,496 133,593 90,373
- -------------------------------------------------------------------------------------------------------------------------
7,524,789 6,698,793 5,900,674 5,953,709 6,416,341 7,081,098 5,679,327
- -------------------------------------------------------------------------------------------------------------------------
5,226,157 4,454,219 4,291,539 4,043,880 4,414,332 4,712,125 3,840,300
350,378 306,687 323,187 298,596 373,171 339,103 223,549
617,871 577,247 583,419 567,142 568,949 503,105 414,791
247,465 245,149 156,615 147,099 177,850 224,200 187,811
851,406 879,679 769,390 773,507 765,877 687,064 492,510
584,161 (c) -- -- -- -- -- --
- -------------------------------------------------------------------------------------------------------------------------
7,877,438 6,462,981 6,124,150 5,830,224 6,300,179 6,465,597 5,158,961
- -------------------------------------------------------------------------------------------------------------------------
(352,649) 235,812 (223,476) 123,485 116,162 615,501 520,366
41,764 162,098 44,727 115,940 31,854 132,788 44,017
- -------------------------------------------------------------------------------------------------------------------------
$ (394,413) $ 73,714 $ (268,203) $ 7,545 $ 84,308 $ 482,713 $ 476,349
=========================================================================================================================
$ (4.26) $ .80 $ (2.91) $ .09 $ 1.05 $ 5.99 $ 5.89
(4.26) .79 (2.91) .09 1.04 5.96 5.87
=========================================================================================================================
$ .60 $ .60 $ .60 $ .60 $ .60 $ .60 $ .60
92,509 92,968 92,213 87,286 81,087 81,023 81,176
=========================================================================================================================
</TABLE>
51
<PAGE> 47
TEN-YEAR SUMMARY OF FINANCIAL DATA
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------------------------------
THOUSANDS OF DOLLARS, EXCEPT PER SHARE DATA 1998 1997 1996
- ---------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
SELECTED BALANCE SHEET DATA AT YEAR-END
Cash and cash equivalents $ 73,791 $ 91,154 $ 112,522
Working capital 89,909 463,781 689,864
Property, plant and equipment
Exploration and production $ 9,718,424 $ 8,779,807 $ 8,233,445
Refining, marketing and other 1,308,815 3,841,828 3,668,974
- ---------------------------------------------------------------------------------------------------------------------------------
Total--at cost 11,027,239 12,621,635 11,902,419
Less reserves 6,835,301 7,430,841 6,995,136
- ---------------------------------------------------------------------------------------------------------------------------------
Property, plant and equipment--net $ 4,191,938 $ 5,190,794 $ 4,907,283
- ---------------------------------------------------------------------------------------------------------------------------------
Total assets $ 7,882,983 $ 7,934,619 $ 7,784,481
Total debt 2,652,465 2,127,288 1,939,288
Stockholders' equity 2,643,412 3,215,699 3,383,631
Stockholders' equity per share $29.26 $35.16 $36.35
=================================================================================================================================
SUMMARIZED STATEMENT OF CASH FLOWS
Net cash provided by operating activities $ 518,788 $ 1,250,007 $ 807,721
- ---------------------------------------------------------------------------------------------------------------------------------
Cash flows from investing activities
Capital expenditures
Exploration and production (1,306,438) (1,157,938) (788,286)
Refining, marketing and other (132,240) (187,652) (72,339)
- ---------------------------------------------------------------------------------------------------------------------------------
Total capital expenditures (1,438,678) (1,345,590) (860,625)
Proceeds from sales of property, plant and equipment and other 502,854 63,017 1,037,073
- ---------------------------------------------------------------------------------------------------------------------------------
Net cash provided by (used in) investing activities (935,824) (1,282,573) 176,448
- ---------------------------------------------------------------------------------------------------------------------------------
Cash flows from financing activities
Issuance (repayment) of notes (14,342) 1,982 (72,046)
Long-term borrowings 848,320 398,391 --
Repayment of long-term debt and capitalized lease obligations (317,144) (209,000) (794,527)
Issuance of common stock -- -- --
Cash dividends paid (54,647) (55,373) (55,746)
Common stock retired (59,167) (122,283) (8,236)
- ---------------------------------------------------------------------------------------------------------------------------------
Net cash provided by (used in) financing activities 403,020 13,717 (930,555)
- ---------------------------------------------------------------------------------------------------------------------------------
Effect of exchange rate changes on cash (3,347) (2,519) 2,837
- ---------------------------------------------------------------------------------------------------------------------------------
Net increase (decrease) in cash and cash equivalents $ (17,363) $ (21,368) $ 56,451
=================================================================================================================================
STOCKHOLDER DATA AT YEAR-END
Number of common shares outstanding (in thousands) 90,357 91,451 93,073
Number of stockholders (based on number of holders of record) 8,959 9,591 10,153
Market price of common stock $49.75 $54.88 $57.88
=================================================================================================================================
</TABLE>
52
<PAGE> 48
<TABLE>
<CAPTION>
- -------------------------------------------------------------------------------------------------------------------------
1995 1994 1993 1992 1991 1990 1989
- -------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
$ 56,071 $ 53,135 $ 79,635 $ 141,014 $ 120,170 $ 129,914 $ 120,300
357,964 520,247 245,026 551,459 625,370 603,244 493,168
$ 9,392,184 $ 9,790,468 $ 9,360,871 $ 9,203,951 $ 9,306,435 $ 8,340,951 $ 6,531,956
3,672,028 4,514,358 4,426,369 3,886,814 3,223,397 2,817,032 2,635,300
- -------------------------------------------------------------------------------------------------------------------------
13,064,212 14,304,826 13,787,240 13,090,765 12,529,832 11,157,983 9,167,256
7,694,496 7,938,824 7,052,328 6,646,801 6,339,232 5,594,399 4,688,142
- -------------------------------------------------------------------------------------------------------------------------
$ 5,369,716 $ 6,366,002 $ 6,734,912 $ 6,443,964 $ 6,190,600 $ 5,563,584 $ 4,479,114
- -------------------------------------------------------------------------------------------------------------------------
$ 7,756,370 $ 8,337,940 $ 8,641,546 $ 8,721,756 $ 8,841,435 $ 9,056,636 $ 6,867,411
2,717,866 3,339,788 3,687,922 3,186,199 3,266,195 2,925,285 2,697,184
2,660,396 3,099,629 3,028,911 3,387,599 3,131,982 3,106,029 2,560,628
$28.60 $33.33 $32.71 $36.59 $38.63 $38.34 $31.69
=========================================================================================================================
$ 1,241,007 $ 957,018 $ 819,423 $ 1,137,707 $ 1,364,268 $ 1,326,444 $ 805,848
- -------------------------------------------------------------------------------------------------------------------------
(626,518) (532,189) (755,419) (916,536) (1,295,039) (1,267,506) (1,730,072)
(65,593) (64,095) (592,622) (641,258) (417,276) (193,921) (98,597)
- -------------------------------------------------------------------------------------------------------------------------
(692,111) (596,284) (1,348,041) (1,557,794) (1,712,315) (1,461,427) (1,828,669)
145,792 72,804 12,436 25,423 37,788 (12,012) 6,644
- -------------------------------------------------------------------------------------------------------------------------
(546,319) (523,480) (1,335,605) (1,532,371) (1,674,527) (1,473,439) (1,822,025)
- -------------------------------------------------------------------------------------------------------------------------
26,247 (54,153) 117,791 (159,756) (183,351) 46,744 13,823
25,000 289,843 547,704 675,016 786,280 461,413 1,203,994
(689,355) (642,112) (167,769) (524,384) (269,414) (287,531) (194,870)
-- -- -- 497,360 -- -- --
(55,788) (55,711) (41,603) (64,194) (36,468) (60,681) (48,785)
-- -- -- -- -- (6,213) (43,632)
- -------------------------------------------------------------------------------------------------------------------------
(693,896) (462,133) 456,123 424,042 297,047 153,732 930,530
- -------------------------------------------------------------------------------------------------------------------------
2,144 2,095 (1,320) (8,534) 3,468 2,877 (7,237)
- -------------------------------------------------------------------------------------------------------------------------
$ 2,936 $ (26,500) $ (61,379) $ 20,844 $ (9,744) $ 9,614 $ (92,884)
=========================================================================================================================
93,011 92,996 92,587 92,584 81,068 81,019 80,804
11,294 11,506 12,000 13,088 13,732 14,669 16,638
$53.00 $45.63 $45.13 $46.00 $47.50 $46.38 $48.75
=========================================================================================================================
</TABLE>
53
<PAGE> 49
TEN-YEAR SUMMARY OF OPERATING DATA
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------------------------
1998 1997 1996
- ------------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
PRODUCTION PER DAY (NET)
Crude oil (barrels)
United States 36,784 35,707 41,020
United Kingdom 109,463 126,427 134,726
Norway 26,943 29,516 27,603
Africa 14,345 10,127 9,725
Indonesia and Azerbaijan 2,949 531 --
Canada and Abu Dhabi -- -- 5,929
- ------------------------------------------------------------------------------------------------------------------------------------
Total 190,484 202,308 219,003
====================================================================================================================================
Natural gas liquids (barrels)
United States 8,136 8,243 9,105
United Kingdom 5,990 6,364 6,628
Norway 1,379 1,657 1,585
Canada -- -- 476
- ------------------------------------------------------------------------------------------------------------------------------------
Total 15,505 16,264 17,794
====================================================================================================================================
Natural gas (Mcf)
United States 293,849 311,915 337,653
United Kingdom 251,000 225,804 253,983
Norway 27,828 30,312 30,445
Indonesia 3,800 1,223 --
Canada -- -- 62,585
- ------------------------------------------------------------------------------------------------------------------------------------
Total 576,477 569,254 684,666
====================================================================================================================================
WELL COMPLETIONS (NET)
Oil wells 28 42 39
Gas wells 20 11 25
Dry holes 25 24 40
PRODUCTIVE WELLS AT YEAR-END (NET)
Oil wells 721 860 854
Gas wells 252 447 455
- ------------------------------------------------------------------------------------------------------------------------------------
Total 973 1,307 1,309
====================================================================================================================================
UNDEVELOPED NET ACREAGE (HELD AT END OF YEAR)
United States 748,000 915,000 891,000
Foreign(a) 16,927,000 10,180,000 7,455,000
- ------------------------------------------------------------------------------------------------------------------------------------
Total 17,675,000 11,095,000 8,346,000
====================================================================================================================================
SHIPPING
Vessels owned or under charter at year-end 9 14 13
Total deadweight tons 952,000 1,602,000 1,236,000
REFINING (BARRELS DAILY)
Amerada Hess Corporation(b) 419,000 411,000 396,000
HOVENSA L.L.C.(c) 433,000 -- --
PETROLEUM PRODUCTS SOLD (BARRELS DAILY)
Gasoline, distillates and other light products 411,000 436,000 412,000
Residual fuel oils 71,000 73,000 83,000
- ------------------------------------------------------------------------------------------------------------------------------------
Total 482,000 509,000 495,000
====================================================================================================================================
STORAGE CAPACITY AT YEAR-END (BARRELS) 56,070,000 87,000,000 86,986,000
NUMBER OF EMPLOYEES (AVERAGE) 9,777 9,216 9,085
====================================================================================================================================
</TABLE>
(a) Includes acreage held under production sharing contracts.
(b) Through ten months of 1998.
(c) Reflects 100% of HOVENSA refinery crude runs from November 1, 1998.
54
<PAGE> 50
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------------------------
1995 1994 1993 1992 1991 1990 1989
- ------------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
52,284 55,638 60,173 62,517 66,063 62,434 60,992
135,429 122,043 80,019 86,265 59,979 56,027 38,707
25,576 24,279 26,388 29,598 28,619 24,351 24,135
9,512 8,857 8,301 6,910 8,952 -- --
-- -- -- -- -- -- --
16,976 17,854 21,540 22,678 21,832 17,969 16,408
- ------------------------------------------------------------------------------------------------------------------------------------
239,777 228,671 196,421 207,968 185,445 160,781 140,242
====================================================================================================================================
10,722 11,964 11,798 11,063 10,047 9,436 9,986
6,900 6,756 3,783 1,468 766 805 466
1,414 1,320 1,432 1,707 1,752 2,004 2,016
1,647 1,809 1,956 1,981 1,997 1,704 1,732
- ------------------------------------------------------------------------------------------------------------------------------------
20,683 21,849 18,969 16,219 14,562 13,949 14,200
====================================================================================================================================
401,581 427,103 502,459 601,824 583,740 457,042 335,112
239,307 208,742 188,024 153,599 128,014 145,921 126,643
27,743 24,417 28,987 31,858 26,947 25,656 24,371
-- -- -- -- -- -- --
215,500 185,856 167,839 137,680 104,151 76,768 72,855
- ------------------------------------------------------------------------------------------------------------------------------------
884,131 846,118 887,309 924,961 842,852 705,387 558,981
====================================================================================================================================
33 28 48 33 45 17 19
41 44 49 20 41 33 19
50 24 37 22 36 38 31
2,154 2,160 2,189 2,082 2,103 2,111 2,048
1,160 1,146 1,115 966 927 905 714
- ------------------------------------------------------------------------------------------------------------------------------------
3,314 3,306 3,304 3,048 3,030 3,016 2,762
====================================================================================================================================
1,440,000 1,685,000 1,854,000 1,819,000 1,802,000 1,716,000 1,589,000
5,871,000 4,570,000 4,310,000 3,168,000 3,480,000 3,329,000 3,083,000
- ------------------------------------------------------------------------------------------------------------------------------------
7,311,000 6,255,000 6,164,000 4,987,000 5,282,000 5,045,000 4,672,000
====================================================================================================================================
16 17 15 21 21 23 22
2,010,000 2,265,000 2,398,000 3,223,000 2,825,000 3,012,000 3,081,000
377,000 388,000 351,000 335,000 320,000 383,000 397,000
-- -- -- -- -- -- --
401,000 375,000 291,000 275,000 285,000 296,000 299,000
86,000 93,000 95,000 102,000 128,000 132,000 171,000
- ------------------------------------------------------------------------------------------------------------------------------------
487,000 468,000 386,000 377,000 413,000 428,000 470,000
====================================================================================================================================
89,165,000 94,597,000 94,380,000 95,199,000 94,879,000 93,867,000 91,794,000
9,574 9,858 10,173 10,263 10,317 9,645 8,740
====================================================================================================================================
</TABLE>
55
<PAGE> 1
EXHIBIT 21
AMERADA HESS CORPORATION AND CONSOLIDATED SUBSIDIARIES
SUBSIDIARIES OF THE REGISTRANT
Organized under
Name of Subsidiary the laws of
- ------------------ ---------------
A.H. Shipping Guaranty Corporation ........................ Delaware
Amerada Hess (CAO) Limited................................. United Kingdom
Amerada Hess (Denmark) A/S ................................ Denmark
Amerada Hess (Falkland Islands) Limited.................... United Kingdom
Amerada Hess Gas Limited................................... United Kingdom
Amerada Hess Gas (Domestic) Limited........................ United Kingdom
Amerada Hess (Indonesia -- Jabung) Limited................. United Kingdom
Amerada Hess (Indonesia -- Pangkah) Limited................ United Kingdom
Amerada Hess International Limited......................... Delaware
Amerada Hess Limitada...................................... Brazil
Amerada Hess Limited ...................................... United Kingdom
Amerada Hess Norge A/S .................................... Norway
Amerada Hess Pipeline Corporation.......................... Delaware
Amerada Hess (Port Reading) Corporation ................... Delaware
Amerada Hess Production Gabon ............................. Gabon
Amerada Hess Shipping Corporation ......................... Liberia
Amerada Hess (Thailand Exploration) Limited................ United Kingdom
Delta Hess (Khazar) Limited................................ United Kingdom
Hess Energy Trading Company, LLC .......................... Delaware
Hess Oil St. Lucia Limited................................. St. Lucia
Hess Oil Virgin Islands Corp. ............................. U.S. Virgin Islands
Jamestown Insurance Company Limited ....................... Bermuda
Other subsidiaries (names omitted because such unnamed subsidiaries, considered
in the aggregate as a single subsidiary, would not constitute a significant
subsidiary)
Each of the foregoing subsidiaries conducts business under the name listed, and
is 100% owned by the Registrant, except for Hess Energy Trading Company, LLC,
which is a trading company that is a joint venture between the Registrant and
unrelated parties.
<TABLE> <S> <C>
<ARTICLE> 5
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 12-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-START> JAN-01-1998
<PERIOD-END> DEC-31-1998
<CASH> 73,791
<SECURITIES> 0
<RECEIVABLES> 1,013,184
<ALLOWANCES> 0
<INVENTORY> 482,182
<CURRENT-ASSETS> 1,886,706
<PP&E> 11,027,239
<DEPRECIATION> 6,835,301
<TOTAL-ASSETS> 7,882,983
<CURRENT-LIABILITIES> 1,796,797
<BONDS> 2,476,145
0
0
<COMMON> 90,357
<OTHER-SE> 2,553,055
<TOTAL-LIABILITY-AND-EQUITY> 7,882,983
<SALES> 6,590,009
<TOTAL-REVENUES> 6,617,466
<CGS> 5,024,405
<TOTAL-COSTS> 5,024,405
<OTHER-EXPENSES> 0
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 152,934
<INCOME-PRETAX> (514,111)
<INCOME-TAX> (55,218)
<INCOME-CONTINUING> (458,893)
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> (458,893)
<EPS-PRIMARY> (5.12)
<EPS-DILUTED> (5.12)
</TABLE>
