<PAGE> 1
================================================================================
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 20-F
<TABLE>
<S> <C>
(MARK ONE)
[ ] REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR
(g) OF THE SECURITIES EXCHANGE ACT OF 1934
OR
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED DECEMBER 31, 1997
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 1-14672
</TABLE>
PETROFINA
(Exact name of registrant as specified in its charter)
<TABLE>
<S> <C>
N/A KINGDOM OF BELGIUM
(Translation of registrant's (Jurisdiction of incorporation
name into English) or organization)
</TABLE>
52 RUE DE L'INDUSTRIE
B-1040 BRUSSELS, BELGIUM
(Address of principal executive offices)
Securities registered or to be registered pursuant to Section 12(b) of the
Act:
<TABLE>
<CAPTION>
TITLE OF EACH CLASS NAME OF EACH EXCHANGE ON WHICH REGISTERED
------------------- -----------------------------------------
<S> <C>
Ordinary Voting Shares New York Stock Exchange*
American Depositary Shares each representing New York Stock Exchange
one-tenth of one Ordinary Voting Share
</TABLE>
Securities registered or to be registered pursuant to Section 12(g) of the
Act: None
Securities for which there is a reporting obligation pursuant to Section
15(d) of the Act: None
Indicate the number of outstanding shares of each of the issuer's classes
of capital or common stock as of the close of the period covered by the annual
report.
23,420,432 Ordinary Voting Shares (as of December 31, 1997)
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 which financial statement item the registrant has
elected to follow.
Item 17 [ ] Item 18 [X]
- ---------------
* Not for trading, but only in connection with the registration of American
Depositary Shares, pursuant to the requirements of the Securities and Exchange
Commission.
================================================================================
<PAGE> 2
TABLE OF CONTENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
1
EXCHANGE RATES.............................................................
2
GLOSSARY...................................................................
3
ABBREVIATIONS..............................................................
3
CONVERSION TABLE...........................................................
PART I
Item 1. Description of Business..................................... 4
Item 2. Description of Property..................................... 27
Item 3. Legal Proceedings........................................... 27
Item 4. Control of Registrant....................................... 27
Item 5. Nature of Trading Market.................................... 28
Item 6. Exchange Controls and Other Limitations Affecting Security
Holders..................................................... 30
Item 7. Taxation.................................................... 31
Item 8. Selected Consolidated Financial Information................. 35
Item 9. Management's Discussion and Analysis of Financial Condition
and Results of Operations................................... 37
Item 9A. Quantitative and Qualitative Disclosures About Market
Risk........................................................ 51
Item 10. Directors and Officers of Registrant........................ 54
Item 11. Compensation of Directors and Officers...................... 58
Item 12. Options to Purchase Securities from Registrant or
Subsidiaries................................................ 58
Item 13. Interest of Management in Certain Transactions.............. 58
PART II
Item 14. Description of Securities to be Registered.................. 58
PART III
Item 15. Defaults upon Senior Securities............................. 59
Item 16. Changes in Securities and Changes in Security for Registered
Securities.................................................. 59
PART IV
Item 17. Financial Statements........................................ 59
Item 18. Financial Statements........................................ 59
Item 19. Financial Statements and Exhibits........................... 59
</TABLE>
i
<PAGE> 3
IN THIS ANNUAL REPORT, (i) REFERENCES TO THE "COMPANY" ARE TO PETROFINA
S.A., AND (ii) REFERENCES TO "PETROFINA" OR THE "GROUP" ARE TO THE COMPANY AND
ITS CONSOLIDATED SUBSIDIARIES. FOR DEFINITIONS OF OTHER TERMS USED HEREIN, SEE
THE GLOSSARY BELOW.
EXCHANGE RATES
Most currency amounts in this Annual Report are expressed in Belgian francs
("Belgian francs" or "BEF") or in United States dollars ("dollars" or "US $").
Solely for the reader's convenience, this Annual Report contains translations of
certain Belgian franc amounts into dollars. These translations should not be
considered representations that the Belgian franc amounts actually represent
such dollar amounts or could be converted into dollars at specified rates.
Unless otherwise stated, the translations have been made at 37.08 Belgian francs
per dollar (US $0.0270 per Belgian franc), the noon buying rate in New York City
for cable transfers in Belgian francs as certified for customs purposes by The
Federal Reserve Bank of New York (the "Noon Buying Rate") on December 31, 1997.
The table below sets forth, for the periods and dates indicated, certain
information concerning the exchange rate for the Belgian franc against the
dollar based on the Noon Buying Rate. Such rates were not used by the Company in
the preparation of its Consolidated Financial Statements included herein.
BELGIAN FRANC/DOLLAR EXCHANGE RATES
(BELGIAN FRANCS PER DOLLAR)
<TABLE>
<CAPTION>
AT END AVERAGE
YEAR OF PERIOD RATE(1) HIGH LOW
---- --------- ------- ----- -----
<S> <C> <C> <C> <C>
1993........................................................ 36.24 34.77 37.18 32.25
1994........................................................ 31.85 33.17 36.53 30.73
1995........................................................ 29.43 29.29 31.94 27.94
1996........................................................ 31.71 31.02 32.27 29.50
1997........................................................ 37.08 35.90 38.82 31.74
1998 (through May 29, 1998)................................. 36.79 37.44 38.50 36.27
</TABLE>
- ---------------
(1) The average of the exchange rates on the last business day of each full
month during the relevant period.
On May 29, 1998, the Noon Buying Rate was 36.79 Belgian francs per dollar
(US $0.027 per Belgian franc).
Fluctuations in the exchange rate will affect the dollar equivalent of the
Belgian franc price of PetroFina Shares on the Brussels Stock Exchange and, as a
result, are likely to affect the market price of PetroFina ADSs in the United
States. Such fluctuations would also affect the dollar amounts received by
holders of the PetroFina ADSs on conversion by the Depositary (as defined below)
of cash dividends paid in Belgian francs on the PetroFina Shares underlying the
PetroFina ADSs. For information regarding the effects of currency fluctuations
on PetroFina's results, see "Item 9. Management's Discussion and Analysis of
Financial Condition and Results of Operations."
1
<PAGE> 4
GLOSSARY
Unless the context indicates otherwise, the following terms have the meanings
shown below:
"acreage".................. The total area, expressed in acres, over which
PetroFina has interests in exploration or
production. "Net acreage" is PetroFina's interest,
expressed in acres, in the relevant exploration or
production area.
"aromatics"................ Organic compounds, such as benzene, which contain
one or more unsaturated cyclic structures with
delocalized electrons.
"ADRs"..................... American Depositary Receipts evidencing PetroFina
ADSs.
"barrels" or "bbls"........ Barrels of crude oil, including condensate and
natural gas liquids.
"catalytic cracking"....... A process by which hydrocarbon molecules are broken
down (cracked) into lighter fractions by the action
of a catalyst.
"condensate"............... Light hydrocarbon substances produced with natural
gas which condense into liquid at normal
temperatures and pressures associated with surface
production equipment.
"conversion"............... Transformation of heavy fractions into light ones.
The term "deep conversion" refers to one such
process used for heavy fuel oils.
"crude oil"................ Crude oil, including condensate and natural gas
liquids.
"desulphuration"........... A generic name given to processes used to eliminate
or reduce various degrees of sulphur in petroleum
products.
"distillation"............. A process by which liquids are separated or refined
by vaporization followed by condensation.
"LPG"...................... Liquefied petroleum gas.
"PetroFina ADSs"........... American Depositary Shares representing the
PetroFina Shares. Each PetroFina ADS represents
one-tenth of one PetroFina Share.
"PetroFina Shares"......... Ordinary voting shares of PetroFina S.A.
"proved reserves".......... Proved oil and gas reserves are the estimated
quantities of crude oil, natural gas and natural
gas liquids which geological and engineering data
demonstrate with reasonable certainty to be
recoverable in future years from known reservoirs
under existing economic and operating conditions.
"proved developed
reserves".................. Proved developed oil and gas reserves are reserves
that can be expected to be recovered through
existing wells with existing equipment and
operating methods. Additional oil and gas expected
to be obtained through the application of fluid
injection or other improved recovery techniques for
supplementing natural forces and mechanisms of
primary recovery are included as "proved developed
reserves" only after testing by a pilot project or
after the operation of an installed program has
confirmed through production response that
increased recovery will be achieved.
"proved undeveloped
reserves".................. Proved undeveloped oil and gas reserves are
reserves that are expected to be recovered from new
wells on undrilled acreage, or from existing wells
where a relatively major expenditure is required
for recompletion, but does not include reserves
attributable to any acreage for which an
application of fluid injection or other improved
recovery technique is contemplated, unless such
techniques have been proved effective by actual
tests in the area and in the same reservoir.
2
<PAGE> 5
"steam cracking"........... A process by which hydrocarbon molecules are split
(cracked) into lighter fractions by steam.
"stream day"............... A day when a refinery is in operation.
ABBREVIATIONS
<TABLE>
<S> <C> <C> <C>
bbl......... barrel /d.......... per day
cf.......... cubic feet /y.......... per year
boe......... barrels of oil equivalent m........... thousand
t........... tonne M........... million
bpsd........ barrels per stream day B........... billion
</TABLE>
CONVERSION TABLE
<TABLE>
<S> <C> <C>
1 barrel..................... = 42 U.S. gallons
1 barrel of oil equivalent... = 1 barrel of crude oil = 6,000 cubic feet of gas(1)
1 barrel of crude oil per = approximately 50 tonnes of
day........................ crude oil (33 API) per year
1 cubic meter................ = 35,315 cubic feet
1 kilometer.................. = approximately 0.62 miles
1 square kilometer........... = 247.1 acres
1 tonne...................... = 1 metric ton = 1,000 kilograms
(approximately 2,203
pounds)
1 tonne of crude oil......... = 1 metric ton of crude oil = approximately 7.3 barrels
of crude oil (assuming a
specific gravity of 33
degrees API (American
Petroleum Institute))
</TABLE>
- ---------------
(1) Natural gas is converted to barrels of oil equivalent using an
industry-accepted ratio of cubic feet of actual gas per barrel.
3
<PAGE> 6
PART I
ITEM 1. DESCRIPTION OF BUSINESS
PetroFina is an international integrated oil and gas company active in all
sectors of the petroleum industry: exploration and production, refining,
marketing of refined petroleum products, petrochemicals and paints.
Headquartered in Brussels (Belgium), the Group has a global presence and employs
over 14,500 people. Founded in 1920, the Company is the fifteenth largest
publicly traded integrated oil and gas company in the world (in each case based
on market capitalization).
PetroFina's operations are organized into four principal business segments:
(1) Upstream (exploration, development and production of crude oil and natural
gas and marketing of natural gas), (2) Downstream (refining, supply and trading
and marketing), (3) Chemicals and (4) Paints.
Upstream. PetroFina currently pursues exploration, development and
production of crude oil and natural gas in 12 countries. In 1997, the Group's
average daily production was 243,000 barrels of oil equivalent per day.
PetroFina estimates that the Group's consolidated proved reserves at December
31, 1997 were 848 million barrels of oil equivalent. Crude oil represented 70%
and natural gas represented 30% of these reserves. PetroFina's reserves are
located principally in the North Sea (Norway and United Kingdom) and the United
States. The Group also markets its U.S. natural gas production through a
division of the Upstream segment. PetroFina's Upstream strategy is to
concentrate its activities in selected geographic areas where it believes it has
technical expertise and good partnerships with governmental bodies and other
commercial producers.
Downstream. PetroFina is engaged in refining crude oil into motor fuels
(gasoline, diesel, jet fuels), kerosene, heating oil, other fuels, base
chemicals and feedstocks for chemical production through six refineries in
Europe, the United States and Angola. As of January 1, 1998, the Group's share
of the refineries' aggregate installed refining capacity was approximately
736,000 barrels per day. PetroFina's marketing operations include a network of
approximately 6,300 service stations in Europe and the United States, marketing
under the brand name "FINA." PetroFina's supply and trading division is also
engaged in trading of crude oil and distilled petroleum products.
Chemicals. PetroFina produces monomers (ethylene, propylene and styrene),
polyolefins (polypropylene and high-density polyethylene), styrene polymers and
copolymers (polystyrene and thermoplastic elastomers) for industrial use, as
well as oleochemicals. In 1997, PetroFina produced 1,900 thousand tonnes of
monomers and 2,170 thousand tonnes of polymers. As of December 31, 1997,
PetroFina was among the top four producers of polypropylene in the world, the
top four producers in the European high-density polyethylene market and the top
three producers in the United States polystyrene market (in each case, based on
combined production capacity and sales volume). The Group has chemical plants at
Antwerp, Feluy, Ghent and Oelegem in Belgium and at La Porte (Texas), Carville
(Louisiana) and Bayport (Texas) in the United States.
Paints. PetroFina owns the Sigma Coatings Group ("Sigma"), which is the
fifth largest producer of decorative paints in Europe based on sales. Sigma also
produces industrial, anti-corrosion and marine paints.
UPSTREAM
OVERVIEW OF UPSTREAM ACTIVITIES
The Upstream segment includes all activities associated with the
exploration, development and production of PetroFina's oil and gas interests,
which are presently located in 12 countries, as well as the Group's natural gas
marketing operations. Since the early 1990s the Group has focused its Upstream
activities on the following core geographic areas: the North Sea, Italy, the
United States, Vietnam and Africa. As a result, PetroFina has discontinued its
exploration activities in a number of non-strategic areas. In addition to its
operations in the core areas, PetroFina has continued to evaluate several other
regions with high potential in the Middle East and the Caspian Sea area in order
to assure the future replacement of its reserves.
As of December 31, 1997, PetroFina had approximately 27,000 square
kilometers (6,671,700 acres) of net exploration acreage. Consistent with
industry practice, PetroFina often holds a percentage interest in its
4
<PAGE> 7
acreage, with the balance held by other joint venture partners (which generally
include other oil companies, state oil companies or government entities).
Contractual arrangements between co-venturers generally are governed by an
operating agreement, which provides for costs, entitlements to production and
liabilities to be shared according to percentage interests, and for one
co-venturer to be appointed operator to conduct operations under the overall
supervision and control of an operating committee consisting of a representative
of each co-venturer. While operating agreements generally provide for
liabilities to be borne by the co-venturers according to their respective
percentage interests, licenses from the relevant government authority generally
provide that the co-venturers are jointly and severally liable for their
obligations to that government authority under the applicable license. These
obligations generally include the removal or decommissioning of installations
upon the cessation of operations. PetroFina has interests in producing acreage
in seven countries and currently acts as an operator in eight countries. See
"-- Upstream Activities by Geographic Region" below for descriptions of the
Group's principal producing fields.
The table below shows the Group's current Upstream activities by country.
<TABLE>
<CAPTION>
EXPLORATION PRODUCTION OPERATOR
----------- ---------- --------
<S> <C> <C> <C>
EUROPE:
Italy.................................................. x x x
Netherlands............................................ x
Norway................................................. x x x
United Kingdom......................................... x x x
NORTH AND SOUTH AMERICA:
United States.......................................... x x x
Falkland Islands....................................... x
Canada................................................. x x
AFRICA:
Angola................................................. x x x
Libya.................................................. x x x
Democratic Republic of Congo (formerly Zaire).......... x x
ASIA:
Vietnam................................................ x x
Azerbaijan............................................. x
</TABLE>
The table below sets forth selected financial data for PetroFina's Upstream
segment for each of the years indicated.
<TABLE>
<CAPTION>
FOR THE YEAR ENDED
DECEMBER 31,
------------------------------
1997 1996 1995
------- ------- -------
(IN MILLIONS OF BEF)
<S> <C> <C> <C>
Total operating revenue..................................... 88,265 65,212 48,598
Inter-segment sales......................................... (36,298) (31,123) (21,687)
Operating revenues to non-affiliates........................ 51,967 34,089 26,911
Operating income............................................ 25,288 24,165 13,400
</TABLE>
EXPLORATION
PetroFina's exploration strategy is to exploit its knowledge and position
in key areas where it has an established operating base (the North Sea, Italy,
the United States and Africa), to continue its exploration activities in areas
where exploration has previously been restricted and which have significant
potential (Vietnam, deep offshore Gulf of Mexico and Libya) and to extend its
activities in areas which have the potential for large discoveries (the Caspian
Sea). PetroFina continuously seeks to consolidate and optimize its portfolio of
net exploration acreage.
PetroFina's total capital expenditures for exploration activities amounted
to BEF 4,576 million, BEF 3,455 million and BEF 2,914 million, for the years
ended 1997, 1996 and 1995, respectively. In 1997, PetroFina participated in 27
exploratory wells, for 16 of which it was operator, and added 2,511 square
5
<PAGE> 8
kilometers (620,468 acres) to its portfolio of net exploration acreage.
Approximately 55% of the completed wells either discovered new potential
reserves of crude oil or natural gas or upgraded existing discoveries. PetroFina
also removed 734 square kilometers (181,371 acres) of acreage in 1997 from its
portfolio of net exploration acreage where appraisals indicated a low
probability of commercial reserves.
Over ten discoveries in Angola, Vietnam, Libya, Alaska and the North Sea
are awaiting appraisal and planning for potential development.
DEVELOPMENT
The development stage occurs after completion of exploration and appraisal
and prior to hydrocarbon production and involves the development of production
facilities including platforms and pipelines. For offshore reserves the
development stage can involve substantial expenditures and time, especially in
areas without existing production infrastructure. PetroFina invested BEF 18,424
million, BEF 14,392 million and BEF 9,297 million, for the years ended 1997,
1996 and 1995, respectively, for development and production facilities.
PetroFina's current activities include new development projects in the
North Sea, North America and Italy, as well as redevelopment of producing
facilities in the North Sea and Africa.
Four new development projects are underway: (1) the Otter oil field in the
U.K. sector of the North Sea (production start-up expected first half of 2000),
(2) the Genesis oil and gas field in the Gulf of Mexico (production start-up
expected end of 1998), (3) the Badami oil field offshore Alaska (production
start-up expected end of 1998), and (4) the onshore Tempa Rossa oil field in the
Apennine mountains of southern Italy (production start-up expected in 2001). In
addition, the Group is preparing a development project of the Girassol field in
the deep waters offshore Angola (production start-up expected end 2000).
PetroFina's largest and most productive Upstream asset, the Ekofisk complex
in the Norwegian sector of the North Sea, is being completely redeveloped at a
cost of over US $2.5 billion to allow for continued production in view of
increasing subsidence of the ocean floor. PetroFina's share of the cost is
estimated to be US $713 million. PetroFina expects the new installations to be
operational in October 1998. Meanwhile, production from the Ekofisk complex
continues at an approximate rate of 93,000 barrels of oil and 252 million cubic
feet of natural gas per day (PetroFina net). For additional information
regarding this redevelopment project, see "-- Upstream Activities by Geographic
Region -- Europe" below. A redevelopment program of the Group's onshore fields
in the Democratic Republic of Congo (formerly Zaire) and a rehabilitation
program of its onshore fields in the province of Congo in Angola are also in
progress.
PRODUCTION
The Group's net production in 1997 was 54 million barrels of oil and 209
billion cubic feet of gas (55% of which was attributable to the Ekofisk complex,
which is under redevelopment), which corresponds to an average daily production
of 243,000 barrels of oil equivalent per day. This production was about 4%
higher than in 1996 and 1995 and 12% higher than in 1994. Europe is the most
significant production area, contributing 87% of total oil production and 63% of
total gas production, or 78% of combined production. The United States
contributes 19% of the Group's aggregate combined production, and the balance
comes from Africa.
6
<PAGE> 9
The following table shows PetroFina's net production for each of the years
indicated by hydrocarbon type and country:
<TABLE>
<CAPTION>
1997 1996 1995
------------------ ------------------ ------------------
OIL GAS OIL GAS OIL GAS
--- --- --- --- --- ---
(MBBL/D) (MCF/D) (MBBL/D) (MCF/D) (MBBL/D) (MCF/D)
<S> <C> <C> <C> <C> <C> <C>
EUROPE
Italy............................. -- 8 -- 7 -- 7
Norway............................ 93 252 89 299 90 327
United Kingdom.................... 36 102 31 106 34 72
NORTH AMERICA
Canada............................ -- 5 -- 4 -- 4
United States..................... 11 205 11 161 11 147
AFRICA
Democratic Republic of Congo
(formerly Zaire)................ 3 -- 4 -- 4 --
--- --- --- --- --- ---
Consolidated Total..................... 143 572 135 577 139 557
EQUITY COMPANIES
Angola............................ 5 -- 3 -- 1 --
--- --- --- --- --- ---
Total........................ 148 572 138 577 140 557
</TABLE>
Approximately 90% of the Group's crude oil production is sold to the
Downstream segment, which either sells or refines the production. The refined
products are either used by the Chemicals segment, sold through the Group's
wholesale and retail petroleum marketing activities or sold through the Group's
supply and trading activities. The rest of the Group's oil and gas production is
sold to third parties. See "Downstream."
RESERVES
At December 31, 1997, the Group's consolidated combined net proved crude
oil and natural gas reserves were approximately 848 million barrels of oil
equivalent, approximately two-thirds of which were oil. 80% of the proved
reserves are located in Europe, 16% in the United States and 4% in Africa.
The table below sets forth PetroFina's estimated worldwide net proved
reserves as of the dates indicated (including both developed and undeveloped
reserves).
<TABLE>
<CAPTION>
NET PROVED RESERVES AT DECEMBER 31,
-----------------------------------------------------------------------
PERCENTAGE PERCENTAGE PERCENTAGE
CHANGE FROM CHANGE FROM CHANGE FROM
1997 1996 1996 1995 1995 1994 1994
----- ----------- ----- ----------- ----- ----------- -----
<S> <C> <C> <C> <C> <C> <C> <C>
Crude Oil (Mbbl).............. 583 3.7 562 2.2 550 3.2 533
Natural Gas (Bcf)............. 1,588 (8.8) 1,742 (1.3) 1,765 1.4 1,741
Combined(1) (Mboe)............ 848 (0.6) 853 1.1 844 2.6 823
</TABLE>
- ---------------
(1) See "Conversion Table" for the ratio used to convert cubic feet of natural
gas to boe.
PetroFina's internal petroleum reservoir engineers estimate proved reserves
using geological and engineering data to determine whether the crude oil or
natural gas in known reservoirs is reasonably certain to be recoverable under
existing economic and operating conditions. This process involves making
subjective judgments. Consequently, measures of reserves are not precise and are
subject to revision. PetroFina's oil and gas reserves are reviewed annually to
take into account, among other things, production levels, field reviews, the
addition of new reserves from discoveries and acquisitions, disposals of
reserves and economic factors. PetroFina's worldwide net proved reserves exclude
the net proved reserves of its non-consolidated company in Angola, in which
PetroFina's proportionate share represented 24.4 million barrels of oil as of
December 31, 1997, 25.7 million barrels of oil as of December 31, 1996, and 26.1
million barrels of oil as of December 31, 1995. For further information
concerning PetroFina's net proved reserves at December 31, 1997, 1996 and 1995,
See "Item 18. Financial Statements -- Supplemental Oil and Gas Information
(Unaudited)."
7
<PAGE> 10
PetroFina's net proved reserves of crude oil and natural gas (calculated on
an oil equivalent basis) have remained stable over the three years ended
December 31, 1997. Over the three-year period from 1995 to 1997, reserve
additions were approximately 300 million barrels of oil equivalent, replacing
113% of production, before deducting sales of reserves in place during this
period. The Group has replaced disposed reserves with new discoveries, improved
enhanced recovery techniques and reserves revisions. The Group's ability to
continue to replace its crude oil and natural gas reserves depends on the
successful outcome of its exploration activities, primarily in Europe and the
United States.
NATURAL GAS MARKETING
The Natural Gas Marketing division markets the Group's United States
natural gas production, as well as third-party produced gas.
UPSTREAM ACTIVITIES BY GEOGRAPHIC REGION
Europe
In NORWAY, the Group holds an interest in 12 offshore licenses and acts as
operator in block 24/9.
The Group has a 30% interest in the Ekofisk, Eldfisk, West Ekofisk, Cod,
Edda and Embla fields, a 22.13% interest in the Tor field, a 15% interest in the
Albuskjell field and a 20.23% interest in the Tommeliten Gamma field.
PetroFina's proved reserves in Norway as of December 31, 1997 were 544 million
barrels of oil equivalent. Total production in 1997 from these fields net to
PetroFina was 33.8 million barrels of crude oil and 92 billion cubic feet of
natural gas.
The ongoing redevelopment of the Ekofisk complex, known as Ekofisk II,
includes two major new platforms, a drilling and production platform and a
platform for processing and transportation of oil and gas. While enhancing
long-term safety, this investment should allow extended incremental recovery and
a significant reduction in operating costs. The Ekofisk partners decided that
certain smaller, substantially depleted fields like West Ekofisk, Cod, Edda,
Albuskjell and Tommeliten should be closed by August 1998 rather than connected
to Ekofisk II. In connection with this redevelopment, the government of Norway
extended PetroFina's operating license from 2011 to 2028. No further royalties
will be due to the government of Norway after Ekofisk II becomes operational in
October 1998. However, in exchange for its contribution of 5% of the
redevelopment costs, the government of Norway will earn 5% of the production
starting in October 1998, and PetroFina's interest will decrease at that point
from 30% to 28.5%.
Enhanced recovery techniques, such as water injection and gas injection,
are very important for the Ekofisk and Eldfisk fields and is being evaluated for
the Tor field. In the Ekofisk field, for instance, the enhanced recovery program
is expected to result in an additional recovery over the life of the field for
the Ekofisk partners of more than 1 billion barrels of oil equivalent.
Oil produced at Ekofisk and its satellite fields is transported by pipeline
to Teesside in the United Kingdom where it is processed. The natural gas is
transported by pipeline to Emden in northern Germany where it is sold to a
consortium of European buyers. The Group holds interests in both the oil
pipeline (28.4%), the gas pipeline and the gas processing plant in Emden
(Germany) (12.9%), and the liquid processing facilities in Teesside (United
Kingdom) (23.75%).
In the UNITED KINGDOM ("U.K."), the Group has interests in 72 offshore
blocks, and is the operator in 18 of them. 27 of these blocks are located west
of Great Britain, including Atlantic Margin Tranche 30 (PetroFina operated) and
Tranche 21.
In the U.K., the Group has an active exploration program including
drilling, appraisal, and continual portfolio consolidation. On average, the
Group has participated in five exploratory wells per year since 1992.
Geographically, the Group's activities are focused in areas with existing
infrastructure for production and transport. Discoveries in the U.K. have
contributed approximately 166 million barrels of oil equivalent to PetroFina's
portfolio of proved reserves since 1992, and PetroFina's proved reserves in the
U.K. as of December 31, 1997 were 128 million barrels of oil equivalent.
The Group's total net oil production in the U.K. for 1997 was 13.2 million
barrels. As of December 31, 1997, net oil production was approximately 39,000
barrels per day, primarily from the three T-block fields
8
<PAGE> 11
(i.e., Toni, Tiffany and Thelma) and the Alba field. PetroFina has a 30%
interest in T-block, which has had a combined field production rate of 70,000
barrels per day since Thelma came on stream in late 1996. The Alba field, in
which PetroFina holds a 12.65% interest, produces at a field rate of almost
100,000 barrels per day.
The development of the Armada complex, which is composed of the Fleming,
Drake and Hawkins gas fields, was completed in 1997 and gas production started
in October 1997. The Group holds a 12.53% interest in this complex.
The Group's gas production in the U.K. totaled 37.4 billion cubic feet in
1997. 41% came from the Audrey and Ann fields in which the Group has a 42.78%
interest, while 20% came from the Hewett field (18.57% interest), a field that
has been producing since the late 1960s. Another 10% came from newcomer Armada
and the balance from several smaller gas fields such as Alison, Amethyst, Dawn
and Everest and from the associated gas produced in the T-block fields.
In ITALY, the Group holds interests in 33 onshore and six offshore licenses
and is operator of eight of them. PetroFina's proved reserves in Italy as of
December 31, 1997 were 4.2 million barrels of oil equivalent.
The Group's gas production from six onshore and two offshore fields reached
three billion cubic feet in 1997, and 130,000 barrels of oil net to the Group
have been produced from a long duration test well on the Tempa Rossa field in
the southern Apennines.
The Tempa Rossa field stretches over several licenses, in two of which the
Group has an average interest of about 20%. In each of the first four wells a
vertical oil column of over 1,000 meters was encountered. During the course of
the next decade, the Group plans a phased development of the field. Initial
production under the first phase, which will include five wells, is planned for
2000. The oil, which is heavy and has a significant sulphur content, will
require special treatment and, therefore, will present both a technical and a
marketing challenge.
In the NETHERLANDS, the Group holds a 17.25% interest in license M/01.
North and South America
In the UNITED STATES ("U.S."), the Group's holdings include interests in 97
blocks in the Gulf of Mexico (58 of which are deep water blocks), and the Group
is the operator in 14 of them. The Group also has interests in four blocks
offshore California and 52 blocks in Alaska (seven onshore and the rest in the
Beaufort Sea). The Group holds additional onshore interests in 18 states. Over
one-third of the Group's acreage in the U.S. is located in Texas.
At the end of 1997, total exploration acreage in the United States amounted
to 5,995 square kilometers (1,481,365 acres). The Group's exploration activities
in the U.S. are conducted primarily offshore in the Gulf of Mexico and in the
Beaufort Sea, and onshore in the Gulf States region.
The Group's U.S. exploration activities increased steadily in 1995 and 1996
after an extensive portfolio consolidation program caused drilling activity to
slow in 1994. In 1997, 1996, and 1995 exploration capital expenditures in the
U.S. amounted to BEF 2,050 million, BEF 1,692 million, and BEF 1,330 million,
respectively. The Group participated in 50, 29, and 17 exploratory wells,
respectively, during these three years. Since 1992, discoveries in the United
States have contributed 110 million barrels of oil equivalent to PetroFina's
portfolio of proved reserves, and PetroFina's proved reserves in the U.S. as of
December 31, 1997 were 138 million barrels of oil equivalent.
In 1997, PetroFina's total net production in the United States was four
million barrels of oil and 77 billion cubic feet of gas.
Onshore the Group has concentrated its exploration efforts in Texas,
Louisiana, Mississippi and Arkansas where several discoveries have been made,
such as in the King Bee, Fandango and McAllen-Pharr areas. During the 1990s the
Group also implemented several tertiary recovery projects in the Permian basin,
including at West Brahaney, North Robertson and East Penwell.
Offshore Louisiana, in the Gulf of Mexico, the Group is concentrating on
deep water prospects. It holds a 30.5% interest in the Mississippi Canyon block
441 field which has produced gas and condensates since 1992.
9
<PAGE> 12
The Group owns a 5% working interest in the Genesis field (Green Canyon blocks),
which is currently under development with initial production of oil and gas
expected by the end of 1998.
Offshore Alaska, in the Beaufort Sea, the Group participated in two
discoveries, Badami and Sandpiper. In 1990, a significant discovery of oil was
made in the Badami oil field in which the Group has a working interest of 30%.
This discovery is currently being developed, and first oil production is
expected in October 1998. The oil produced at Badami will be transported 25
miles to the existing Endicott field and from there will enter into the Trans
Alaska pipeline to Valdez in southern Alaska. The potential of Sandpiper, in
which the Group's working interest is 42.4%, is still in the exploration phase.
In CANADA, PetroFina produces approximately 4.5 million cubic feet of
natural gas per day through its participation in two discoveries. The Group also
participates in exploration activities in western Canada.
In 1996, the Group obtained a 25% stake in a license called Tranche A,
north of the FALKLAND ISLANDS. Seismic studies are in progress in preparation
for the drilling of a first exploration well in 1998.
Africa
In ANGOLA, PetroFina is the operator in fields located in the onshore
Kwanza and Congo basins. Its share of oil production from these fields in 1997
totaled 1.7 million barrels. Production in Angola has been increasing steadily
as a result of the ongoing rehabilitation of the Soyo area following damage to
wells and installations in 1993 and 1994 during the civil war. The total daily
production operated by PetroFina had increased to 20,000 barrels by the end of
1997, and PetroFina anticipates that this production will further increase to
its maximum of 25,000 barrels daily by the end of 1998. The oil from the Congo
basin is exported through an offshore, third-party-operated terminal.
PetroFina's interest in Upstream activities in Angola is reflected in the
Consolidated Financial Statements according to the equity method of accounting.
See "Item 18. Financial Statements."
Offshore Angola, the Group's activities are conducted through a
wholly-owned subsidiary, which is involved in exploration and appraisal of Block
17. It has a 5% interest in the joint venture that discovered the Girassol field
in 1996. In August 1997, a second oil discovery in Block 17 was made in the
Dalia field. Initial production tests indicated a cumulative flow rate of 16,000
barrels per day. A third discovery, called Rosa, was made in the beginning of
1998 and again its initial production tests indicated rates above 12,000 barrels
per day. While the joint venture is continuing its exploration efforts by
drilling other structures in the block, the development of the Girassol field
will be decided in 1998 with first production expected by the end of the year
2000. PetroFina has been appointed operator for Block 19 offshore Angola,
located in the deepwater offshore Luanda, at the northern edge of the Kwanza
basin, with a 30% interest. Negotiations with the Angolese authorities
concerning a Production Sharing Agreement are expected to commence in the near
future.
In the DEMOCRATIC REPUBLIC OF CONGO (formerly Zaire), the Group is the
operator with a 54.5% interest in three coastal onshore licenses. Its share of
the oil produced from six different fields was 1.1 million barrels in 1997.
The Group is an operator with a 60% interest in three licenses of the Sirte
oil basin in LIBYA, where it has drilled 10 wells. These wells have resulted in
two small discoveries, which will be evaluated in an extended production test
that started in December 1997 and which will run for one year. The initial gross
production was 5,000 barrels per day.
East Asia
In VIETNAM, the Group is the operator, with a 100% interest, of offshore
blocks 46, 50 and 51. Since 1996, six wells have resulted in six oil and gas
discoveries in these blocks. During 1997, a three-dimensional seismic survey was
conducted in order to determine the development potential of these discoveries.
One of the discovery wells confirmed that the Bunga Kekwa field, in which
production started in 1997, stretches into block 46. Bunga Kekwa is located in
the zone that is jointly managed by Vietnam and Thailand.
Central Asia
In the first half of 1997, PetroFina launched its first project in the
Caspian Sea by acquiring a 5% interest in the exploration of a block offshore
AZERBAIJAN covering the Lenkoran and Talysh structures.
10
<PAGE> 13
DOWNSTREAM
OVERVIEW OF DOWNSTREAM ACTIVITIES
The Downstream segment includes PetroFina's crude oil refining, supply and
trading, and wholesale and retail petroleum products marketing activities.
With respect to refining, PetroFina's strategy is to be an efficient
operator of individual refineries with the flexibility to adapt to different
crude and feedstock supplies in order to enable it to meet changing market
requirements. PetroFina's supply and trading activity is focused on obtaining
both (1) crude oil and other raw materials needed for the Group's refinery
operations and (2) refined petroleum products to meet the needs of the Group's
marketing activities. The marketing activities focus on wholesale and retail
sales of refined petroleum products and lubricants, primarily in Europe and the
United States.
The table below sets forth selected financial data for PetroFina's
Downstream segment for each of the years indicated.
<TABLE>
<CAPTION>
FOR THE YEAR ENDED DECEMBER 31,
---------------------------------
1997 1996 1995
------- ------- -------
(IN MILLIONS OF BEF)
<S> <C> <C> <C>
Total operating revenue..................................... 571,964 496,361 441,688
Inter-segment sales......................................... (16,961) (13,757) (16,448)
Operating revenues to non-affiliates........................ 555,003 482,604 425,240
Operating income............................................ 12,005 5,195 235
</TABLE>
REFINING
As of January 1, 1998, PetroFina had six refineries, in which the Group's
aggregate share of the total installed crude processing capacity was 36 million
tonnes per year (736,000 bpsd): (1) Fina Raffinaderij Antwerpen ("FRA") in
Antwerp (Belgium), (2) Lindsey Oil Refinery ("LOR") (PetroFina interest 50%) in
Killingholme (U.K.), (3) the Port Arthur Refinery in Texas (U.S.), (4) the Big
Spring Refinery in Texas (U.S.), (5) Raffineria di Roma ("RdR") (PetroFina
interest 57.5%) in Rome (Italy) and (6) the Luanda Refinery in Angola. In
addition, the Group has access to refining capacity in France through various
processing contracts.
In refining, the Group's objectives are (1) to enhance refining flexibility
by optimizing the production of gasolines, middle distillates and chemical
feedstocks compared to heavy fuel oil, (2) to improve energy efficiency and (3)
to increase the integration of PetroFina's refineries with its chemical plants.
Fulfillment of these objectives will help the Group meet the growing demand for
high value-added products and for products which conform to more stringent
environmental standards.
The refining industry has suffered from continuing erosion of refining
margins during the 1990s. Technological improvements in plant efficiency and
expectations for future product demand have led to an imbalance in the market
between capacity and product demand. While the eventual market effect of the
structural oversupply is expected to be the closure of less efficient plants,
the short-term effect is continued adverse pressure on the sector's
profitability. At the same time, the refining industry requires ongoing capital
investments to enable it to meet future product specifications, especially those
related to environmental regulatory developments.
To counteract the industry conditions described above and to achieve its
strategy, the Group has sought to optimize the size and efficiency of its
refining and lubricating oil blending plants and its retail stations, while
maintaining regional balance between refined product supply and retail station
demand. In addition, the Group intends to continue to maximize the upgrading
capacity of its individual refining units in Europe and the United States. Over
the three-year period ended December 31, 1997, the Group invested BEF 9,603
million in its refineries.
11
<PAGE> 14
The table below sets forth PetroFina's share of the daily crude oil
refining capacities of the Group's refineries.
<TABLE>
<CAPTION>
GROUP'S SHARE OF DAILY
CRUDE OIL
REFINERY CAPACITY AT
JANUARY 1, 1998(1)
--------------------------
<S> <C>
FRA......................................................... 305
LOR(2)...................................................... 100
Port Arthur................................................. 183
Big Spring.................................................. 60
RdR(3)...................................................... 49
---
CONSOLIDATED TOTAL.......................................... 697
EQUITY COMPANIES
Luanda(4).............................................. 39
---
TOTAL....................................................... 736
</TABLE>
- ---------------
(1) In the case of refineries that are not wholly owned by the Group, the
indicated capacity represents the Group's proportionate share of the total
refining capacity of the refinery.
(2) PetroFina interest 50%.
(3) PetroFina interest 57.5%.
(4) This refinery is owned and operated by a non-consolidated subsidiary.
The table below sets forth, for the years indicated, the amount of crude
oil processed for PetroFina's account at the Group's refineries (excluding the
Luanda refinery).
<TABLE>
<CAPTION>
1997 1996 1995
---- ---- ----
<S> <C> <C> <C>
Actual throughput (Mt/y).................................... 32.9 31.8 29.3
Utilization................................................. 97.3% 98.1% 93.0%
Total installed capacity (Mt/y)............................. 35.8 32.4 31.5
</TABLE>
Europe
PetroFina's European refining units are considered industry leaders in
terms of flexibility of access to market through pipeline facilities and captive
local consumption, as well as to the sea and convenient shipping facilities, and
conversion ratings (the ability to produce value-added products) having one of
the highest conversion to distillation ratios in Europe (40%, compared to an
industry average of 32%). The high desulphuration capacity of middle distillates
and fuel oils allows the Group to comply with the European Union's year 2000
sulphur specification for diesel and fuel oils without major additional
investments. The MTBE units (defined below) at FRA and LOR, the TAME unit
(defined below) at LOR and the catalytic reforming unit with a continuous
catalyst regeneration system at FRA give the Group the ability to supply
directly the whole of its European retail network's demand for high octane
unleaded gasoline.
Antwerp. FRA is the Group's largest refinery, accounting for over 40% of
the Group's total crude distillation capacity, and is the fourth largest
refinery in Western Europe (based on throughput capacity).
FRA has an installed atmospheric distillation capacity of 15.3 million
tonnes of crude oil per year with associated vacuum distillation capacity for
the treatment of residue feedstocks. It has two catalytic crackers with a total
capacity of 4.1 million tonnes of crude oil per year whose capacity has
increased by approximately 10% over the last 10 years and whose conversion of
heavy fractions into light products has increased by approximately 5% over the
past 10 years. It also has a visbreaker (a cracking process plant which, at
moderate temperatures, reduces the viscosity of heavy petroleum fractions) with
a capacity of 2.5 million tonnes per year; product desulphuration units and
sulphur recovery plants; an MTBE (Methyl-Tertiary-Butyl-Ether) unit with
capacity of 180,000 tonnes per year; a jet fuel treatment unit with capacity of
680,000 tonnes per year; and a propylene fractionation unit able to produce
200,000 tonnes of chemical grade propylene per year. An alkylation unit, which
has a capacity of 270,000 tonnes per year, as well as a catalytic reforming unit
with a continuous catalytic regeneration section, which has a capacity of 2.3
million tonnes per year, permits the
12
<PAGE> 15
manufacture of several grades of unleaded gasoline in the European Union in
response to increasingly stringent environmental specifications.
Since 1994, FRA has been equipped with a deep conversion facility with a
capacity of 3.4 million tonnes per year. This facility enables FRA to produce,
after desulphuration, a high quality product slate from "poorer" quality crudes,
making it one of the most modern and efficient refineries in Europe.
The Group has begun construction of a unit to increase its production of
aromatics (including xylene) by 800,000 tonnes per year by the year 2000, with a
corresponding decrease in gasoline production. PetroFina plans to invest
approximately BEF 4 billion in this unit. PetroFina has signed a long-term
supply agreement with Amoco under which Amoco will purchase xylene produced at
FRA.
At the end of 1997, discussions were finalized and the Group signed a
contract with Electrabel, the Belgian electricity company, in January 1998, to
build a cogeneration unit at FRA.
Lindsey Oil Refinery. The Group owns a 50% interest in LOR at Killingholme
in the northeast of England, which has an installed atmospheric distillation
capacity of 9.6 million tonnes per year with associated vacuum distillation
units which can also treat imported residue feedstocks. LOR has a catalytic
cracker (which was upgraded recently to increase gasoline production and
conversion and to meet anticipated environmental regulations) with a capacity of
2.5 million tonnes per year; two semi-regenerative catalytic reforming units
with a total capacity of 1.4 million tonnes per year; a visbreaker with a
capacity of 1.6 million tonnes per year, and desulphuration units and sulphur
recovery plants. It also has a kerosene treatment unit with a capacity of
780,000 tonnes of jet fuel per year; a kerosene dearomatization unit with a
capacity of 140,000 tonnes per year; and a bitumen production unit with a
capacity of 600,000 tonnes per year. The refinery also has a catalytic
polymerization unit, with a feedstock capacity of 120,000 tonnes per year, that
transforms light olefins from the cracker into gasoline, as well as two
propylene fractionating units, with a capacity of 160,000 tonnes per year and an
alkylation unit (equipped with a hydroisomerization feedstock preparation
section) with a capacity of 250,000 tonnes per year. The refinery has an MTBE
unit with a capacity of 100,000 tonnes per year and a TAME
(Tertiary-Amyl-Methyl-Ether) unit with a capacity of 50,000 tonnes per year.
Since 1992, the Group has completed capital projects involving system
automation for managing oil products, finished product loading and catalytic
cracking capacity increases. In addition, in a joint venture with a major
electric utility company, in November 1996, the Group completed the installation
of a 40 megawatt cogeneration unit to produce electricity and steam to supply
LOR's own needs, while leaving a substantial proportion of electricity for sale.
The cogeneration unit reduces the refinery's energy costs in an environmentally
sensitive manner.
Rome. In Italy, the Group owns a 57.5% interest in RdR, a refinery near
Rome. The refinery has an installed atmospheric distillation capacity of 4.0
million tonnes per year and a vacuum distillation unit with a capacity of
630,000 tonnes per year. RdR has a visbreaker with a capacity of 1.7 million
tonnes per year, distillate desulphuration units and a sulphur plant for liquid
sulphur recovery. It is equipped with a semi-regenerative catalytic reformer
unit with a capacity of 600,000 tonnes per year, a kerosene treatment unit with
a capacity to produce 530,000 tonnes of jet fuel per year and an isomerization
unit with a capacity of 240,000 tonnes per year.
A new benzene saturation unit was commissioned in November 1997. This unit
produces low benzene gasoline to be marketed in the Rome region.
United States
Port Arthur. The Port Arthur refinery, on the Texas Gulf coast, has an
installed atmospheric distillation capacity of 8.8 million tonnes per year with
associated vacuum distillation capacity. Since 1991, it has had a catalytic
cracking unit with a capacity of 3.1 million tonnes per year. In the 1980s an
upgrading program reduced the output of lower value heavy residues to 8% and
allowed the production of unleaded gasoline following the installation of a
reforming unit with a continuous regeneration system. In addition, this program
included a vacuum bottom deasphalting unit with a capacity of 1.0 million tonnes
per year and a desulphuration unit for heavy cracker feedstock with a capacity
of 1.4 million tonnes per year. The Port
13
<PAGE> 16
Arthur refinery also has a 36-megawatt cogeneration unit which supplies most of
the refinery's electricity and steam requirements. This cogeneration unit, which
was installed in 1988, substantially reduced the plant's operating costs. The
refinery also has distillate desulphuration units with associated sulphur
recovery plants and an alkylation unit with a capacity of 210,000 tonnes per
year. The complex includes a unit for the extraction of aromatics from gasoline,
which supplies half of the benzene feedstock requirements of the Group's
petrochemical plants in the United States, and an isomerization unit with a
capacity of 373,000 tonnes per year.
Big Spring. The Big Spring refinery, in Howard County, Texas, has an
installed atmospheric distillation capacity of 2.9 million tonnes per year and
an associated vacuum distillation unit; a catalytic cracker with a capacity of
1.2 million tonnes per year; an alkylation unit with a capacity of 195,000
tonnes per year; a solvent deasphalting unit with a capacity of 560,000 tonnes
per year; and desulphuration with associated sulphur recovery units.
This refinery also has a semi-regenerative catalytic reformer unit with a
capacity of 850,000 tonnes per year and an aromatic extraction unit for benzene
recovery, with a capacity of 30,000 tonnes of benzene per year. In 1996, the
fluid catalytic cracking unit was upgraded which increased the conversion
capacity by 7%.
Fina, Inc. has negotiated access to a pipeline network that will link the
Big Spring refinery to El Paso (Texas), Albuquerque (New Mexico) and Tucson
(Arizona).
Africa
Luanda. The Group owns the only refinery in Angola, which is in Luanda. It
has an installed atmospheric distillation capacity of 1.9 million tonnes per
year, a semi-regenerative catalytic reformer with a capacity of 71,000 tonnes
per year and a vacuum unit with a capacity of 140,000 tonnes per year. The
Group's activities at the Luanda refinery are conducted by a non-consolidated
subsidiary of the Company. The prices of refined products are fixed by the
government so that the Group obtains a specified return on its capital invested
in the refinery.
SUPPLY AND TRADING
The Group's supply and trading activities are focused principally on the
supply of its refineries, as well as its marketing entities. Its supply
department is active in both physical and, to a limited extent, futures markets.
Spot and term crude oil and feedstocks supply contracts cover the quantity
and quality requirements of PetroFina's refineries. Exchange and processing
agreements allow the Group to ensure the security and the optimization of the
supply of petroleum products to its various marketing organizations. Like most
other oil companies, the Group uses hedging tools to moderate its exposure to
short-term fluctuations in crude and products prices. See "Item 9A. Quantitative
and Qualitative Disclosures About Market Risk."
The supply and trading division's activities include the trading of
significant amounts of refined petroleum products (including the trading of
liquefied petroleum gas) on the international markets, mainly in Europe and in
the United States. It also manages the supply of the feedstocks required by Fina
Antwerp Olefins petrochemical complex.
14
<PAGE> 17
The table below sets forth selected information with respect to the Group's
sales and supply of crude oil (produced by PetroFina and by third parties) for
each of the years indicated.
<TABLE>
<CAPTION>
FOR THE YEAR ENDED
DECEMBER 31,
------------------------------
1997 1996 1995
-------- -------- --------
(IN THOUSANDS OF TONNES)
<S> <C> <C> <C>
PETROFINA CRUDE PROCESSED IN PETROFINA REFINING SYSTEM:
Europe(1)................................................. 5,399 4,625 4,205
United States............................................. 0 1,118 1,208
------ ------ ------
Total................................................ 5,399 5,743 5,413
PETROFINA CRUDE SOLD TO THIRD PARTIES:
Europe(1)................................................. 869 1,095 1,461
United States............................................. 507 506 512
------ ------ ------
Total................................................ 1,376 1,601 1,973
THIRD-PARTY CRUDE PURCHASED AND PROCESSED IN PETROFINA
REFINING SYSTEM:
Europe(1)................................................. 16,717 17,175 14,795
United States............................................. 9,569 8,943 9,115
------ ------ ------
Total................................................ 26,286 26,118 23,910
THIRD-PARTY CRUDE PURCHASED AND RESOLD TO THIRD PARTIES:
Europe(1)................................................. 703 419 1,917
United States............................................. 5,730 1,370 1,179
------ ------ ------
Total................................................ 6,433 1,789 3,096
</TABLE>
- ---------------
(1) Europe includes Europe and the rest of the world, other than the United
States.
For additional information, see "Item 9A. Quantitative and Qualitative
Disclosures About Market Risk."
MARKETING
PetroFina markets refined petroleum products (such as gasoline, diesel,
heating oil, and industrial, aviation and marine fuels, as well as bitumen) and
lubricants throughout the world under the brand name FINA. Its primary sales
activity is, however, concentrated in Europe and the United States. PetroFina
also conducts some marketing activities, with a special emphasis on lubricants,
in a number of countries in Africa and Asia. In 1997, the Group's sales volume
of refined products and lubricants amounted to 38.7 million tonnes, a 3.8%
increase over 1996.
The table below sets forth by geographic area for the years indicated the
Group's sales of refined petroleum products and lubricants for the periods
indicated.
<TABLE>
<CAPTION>
FOR THE YEAR ENDED
DECEMBER 31,
------------------------------
1997 1996 1995
-------- -------- --------
(IN THOUSANDS OF TONNES)
<S> <C> <C> <C>
Europe.............................................. 26,161 25,278 24,367
United States....................................... 12,540 12,016 12,378
------ ------ ------
Total.......................................... 38,701 37,294 36,745
</TABLE>
PetroFina's marketing activities are divided into two sectors: retail and
commercial. The retail activities are those carried out mainly through its
network of approximately 6,300 retail service stations in Europe and the United
States. At December 31, 1997, 3,615 service stations were located in nine
European countries and 2,659 in the United States. The commercial or wholesale
activities are bulk sales to both distributors and direct consumers, which
include the aviation and marine markets as well as the sale of heating and
industrial oils.
15
<PAGE> 18
PetroFina's marketing strategy for its retail and commercial operations is
to concentrate in geographic areas where it has logistical strengths,
particularly areas near its refineries and storage terminals or near third-
party depots where the Group obtains products through exchange agreements. In
order to achieve its marketing objectives, the Group has embarked on a series of
asset exchanges, acquisitions and disposals, especially in the U.K., France and
Germany. At the same time, the Group is improving the efficiency of its retail
network by reducing its operating costs, and upgrading the quality of its
network. The upgrading program includes, among other things, a new visual
identification program and enhanced customer services, such as a new convenience
store concept and expanded car wash facilities, at the service stations.
The Group supplies jet fuel to approximately 100 airlines at various major
European and U.S. airports. The majority of the sales are supplied directly from
the Group's refineries, which enables PetroFina to provide, by its control over
the supply chain, a secure and cost effective supply source. Annual sales of jet
fuels increased by 1.5% in 1997 to 2.2 million tonnes. PetroFina also supplies
marine fuels to seagoing and other vessels from supply points in ports located
near its refineries.
The Group produces lubricant products at its three blending plants located
in Europe and East Asia. These products are sold in more than 50 countries.
Continuous product innovation is necessary in this highly competitive market
because of consumer demand for environmentally acceptable products, the
increasing efficiency of engines and the technical development of industrial
plants. The Group's strategy is to concentrate on selected market segments for
which PetroFina has developed an expertise, such as special vehicle dealers and
transport companies, which use automotive oils, and the steel industry, paper
mills and building materials industry, which use industrial lubricants.
The Group also produces high-quality greases at its Beverwijk plant in the
Netherlands, which are marketed to heavy industries, such as the iron and steel
industry, and paper mills or cement factories.
The Group's total lubricants and greases sales amounted to approximately
251,000 tonnes in 1997.
PetroFina sponsors FINA racing teams that participate at various European
and U.S. car races and use Fina fuel and high performance lubricants.
Europe
In Europe, the FINA retail network extends through Belgium, England,
France, Germany, Italy, Luxembourg, the Netherlands, Norway and Spain. The Group
also conducts wholesale or lubricant marketing activities in Denmark, Poland,
Portugal and Switzerland.
The table below sets forth the number of FINA service stations in Europe by
country for the last three years.
<TABLE>
<CAPTION>
NUMBER OF STATIONS
AT DECEMBER 31,
------------------------------
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
Belgium................................................ 521 531 564
France................................................. 437 451 482
Germany................................................ 398 432 442
Italy.................................................. 1,380 1,355 1,381
Luxembourg............................................. 18 18 19
The Netherlands........................................ 191 172 170
Norway................................................. 178 201 199
Spain.................................................. 68 64 52
United Kingdom......................................... 424 452 502
----- ----- -----
Total............................................. 3,615 3,676 3,811
</TABLE>
16
<PAGE> 19
The table below sets forth the number of stations in Europe owned by the
Group, FINA-branded distributor stations and the total number of stations over
the three years indicated.
<TABLE>
<CAPTION>
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
Group-owned stations................................... 1,816 1,853 1,900
FINA-branded distributor stations...................... 1,799 1,823 1,911
----- ----- -----
Total stations.................................... 3,615 3,676 3,811
</TABLE>
PetroFina is pursuing a retail network consolidation and upgrading program
across Europe, seeking to concentrate sales volume at a smaller number of more
efficient sites in selected regions, while at the same time reinforcing and
harmonizing the "FINA" brand image.
The Group continues to increase the number of service stations under direct
management thus improving customer service and the commitment of the network's
employees.
During the three years ended December 31, 1997, the Group reduced the
number of service stations throughout its European network by 7.1%, while it
increased its average sales volume per site by 19.5%.
At the end of 1994, PetroFina launched the Eurotrafic card, an
international electronic payment system aimed at corporate customers. The card,
which is accepted in 4,500 service stations in 13 European countries, provides
fleet management services, such as VAT (value added tax) recovery, toll payments
and roadside assistance. Loyalty cards aimed at both business and private
customers are also being developed by PetroFina's marketing subsidiaries on a
country-by-country basis.
In its home country, Belgium, PetroFina has a retail market share of
approximately 13%, while its Italian network is the largest contributor (29%) to
the Group's European retail sales. The Group also has a significant retail
market share in Britanny (France) and Eastern England. Currently, the largest
capital budgets in terms of retail network are in Italy and Germany. In Italy a
program of 10 to 12 new service stations per year is planned for the Rome,
Lombardy and Tuscany regions, while at the same time existing sites with the
most favorable prospects for a long term future are being modernized and
re-imaged. In 1997, the Group received 20 service stations in western Germany in
exchange for the majority (17 sites) of the Group's network in eastern Germany.
In Germany, more than 20% of the European retail budget is being directed to new
sites and the modernization of the network in three key regions: the Rhein-Main
metropolitan area, central Germany, and southwestern Germany. Elsewhere in
Europe, the Group is actively developing a retail network in northern Spain,
while consolidating its position in Belgium, the Netherlands and Norway.
PetroFina is reinforcing its position in bulk wholesale and commercial
markets throughout its nine European core countries, especially in areas around
its refineries and its main depots. In Europe, the aggregate sales in these
markets amounted to 13 million tonnes in 1997.
A new lubricants blending and packaging plant at Ertvelde (Belgium) with a
capacity of 120,000 tonnes per year, serves as the Group's logistical center for
the northern European market. Additional Group production, blending and
packaging takes place at Valdemoro (Spain), which serves southern Europe. In
January 1998, the Group sold its blending plant at Duisburg (Germany), which
allows PetroFina to concentrate its lubricants' production at Ertvelde (Belgium)
and achieve important economies of scale.
The Group also wholesales bitumen, particularly from FRA, LOR and RdR, its
Antwerp, and Killingholme and Rome refineries, which produce 453,000 tonnes per
year. In the U.K., the Group is active in the bitumen market through its
subsidiary LanFina.
United States
In the United States, marketing activities have been divided into two
geographic business units since 1994 with the aim of reducing costs, increasing
productivity and improving customer service. The U.S. marketing focus is to
enable the maximization of PetroFina's refinery utilization through both FINA
branded and unbranded fuel sales.
17
<PAGE> 20
The table below sets forth the number of stations in the United States
owned by the Group, the number of FINA-branded distributor stations and the
total number of stations over the three years indicated.
<TABLE>
<CAPTION>
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
Group-owned stations................................... 53 38 38
FINA-branded distributor stations ..................... 2,606 2,540 2,664
----- ----- -----
Total stations.................................... 2,659 2,578 2,702
</TABLE>
The Southeastern Business Unit manages supply and marketing activities in,
and east of, the Dallas/Ft. Worth area in Texas and throughout the Gulf States
region, including the Group's owned and operated convenience store outlets and
the Port Arthur refinery. The Southwestern Business Unit manages marketing
activities west of Ft. Worth, Texas (principally, west Texas and New Mexico) and
includes crude gathering operations and the Big Spring refinery. As of January
1, 1996, the Group took a 34.4% interest in Southwest Convenience Stores, which
owns and operates 163 convenience stores in west Texas and New Mexico under
exclusive licensing arrangements using the 7-Eleven brand and which is supplied
with all its fuel requirements by the Group.
CHEMICALS
PetroFina's Chemicals segment produces and markets petrochemicals (base
chemicals, monomers, polymers) and oleochemicals. The Group conducts a wide
range of chemical activities at five plants in Europe and five plants in the
United States. These plants, which are close to large markets, have access to
some of the world's largest harbors and best transportation networks (pipelines,
rivers, channels, railways and highways). These logistical advantages enable
PetroFina to deliver high-quality products at low cost. Over the last three
years, PetroFina has invested an aggregate of BEF 20,663 million in its chemical
monomer and polymer production facilities.
Through its research and development activities, PetroFina is extending the
Group's range of products and services, utilizing a customer-driven approach.
The Chemicals segment's strategy for growth is based on three principles:
(1) extensive integration from crude oil to polymers; (2) use of large plants to
maximize efficiency; and (3) developing differentiated products, while remaining
a low-cost producer. Where appropriate, this strategy has been pursued through
joint ventures.
The table below sets forth selected financial data for the Chemicals
segment for each of the years indicated.
<TABLE>
<CAPTION>
FOR THE YEAR ENDED
DECEMBER 31,
------------------------------
1997 1996 1995
-------- -------- --------
(IN MILLIONS OF BEF)
<S> <C> <C> <C>
Total operating revenue............................. 93,247 78,404 79,941
Inter-segment sales................................. (5,116) (3,421) (2,744)
Operating revenues to non-affiliates................ 88,131 74,983 77,197
Operating income.................................... 10,439 11,337 19,014
</TABLE>
18
<PAGE> 21
The table below shows the Group's year-end petrochemical production
capacity at the dates indicated.
<TABLE>
<CAPTION>
CAPACITY AT DECEMBER 31,
------------------------
1997 1996 1995
---- ---- ----
(IN THOUSANDS OF TONNES)
<S> <C> <C> <C>
EUROPE
Ethylene.......................................... 680 676 650
Propylene......................................... 610 580 565
Aromatics......................................... 200 200 200
High density polyethylene......................... 450 450 450
Elastomers........................................ 80 80 80
Polystyrene(l).................................... -- -- 85
Polypropylene..................................... 400 385 385(2)
UNITED STATES
Propylene......................................... 270 270 145
Aromatics......................................... 580 580 580
Styrene........................................... 480 476 418
Polystyrene....................................... 465 450 351
Polypropylene..................................... 700 680 617
High density polyethylene......................... 191 191 182
</TABLE>
- ---------------
(1) The Group sold its European interest in polystyrene production in March
1996.
(2) The Group acquired the remaining interest (50%) in Fina Chemicals Feluy in
March 1995.
EUROPE
The Group's European chemical activities are carried out in five plants in
Belgium located at Antwerp (two plants), Feluy, Ertvelde and Oelegem. These
plants, which are operated by Company subsidiaries and a joint venture, produce
a variety of monomers, polymers, base chemicals and oleochemicals.
Petrochemicals
Consistent with the segment's strategy, PetroFina's petrochemical plants
are integrated with its refineries. More than 40% of the feedstocks used in its
European plants are supplied from internal sources, and the refineries are able
to use return streams of various by-products, including hydrogen, from the
chemical plants.
19
<PAGE> 22
The table below illustrates, in a simplified and schematic manner, the
major changes which the main products of PetroFina's European petrochemical
plants undergo, as well as their vertical integration.
[FLOWCHART]
(1) The Group operates a polysterene plant on behalf of the
third party to whom PetroFina sold its interest in March
1996.
The Group's European chemical products are marketed through a "FINA
Chemicals" branded organization supported by offices throughout Western Europe,
Poland, Russia and Asia. This organization works closely with the plants and the
Group's research and development center in Feluy to better respond to customer
needs.
Antwerp. The Group's petrochemical activities in Antwerp are carried out
at two plants close to FRA, its Antwerp refinery. These plants are operated by
the Company's subsidiary Fina Chemicals Antwerp and a joint venture in which the
Group has a 65% interest, Fina Antwerp Olefins ("FAO"). The Group's refining and
petrochemical center in Antwerp (Belgium), one of the world's largest, benefits
from its location in a
20
<PAGE> 23
geographical area that must import significant quantities of base chemicals to
meet local demand. Feedstocks produced at FRA are converted to monomers such as
ethylene and propylene at FAO.
FAO operates three steam crackers with a capacity of more than 1 million
tonnes of ethylene per year, representing more than 5% of total installed
capacity in Western Europe. The third steam cracker, constructed at the center
of FRA, provides an ethylene capacity of about 500,000 tonnes per year which,
following a debottlenecking program, is expected to reach 550,000 tonnes per
year in the spring of 1998. FAO is connected by pipeline network to more than
40% of the Western European ethylene market. It also operates a 20,000 tonne
capacity ethylene storage terminal. The Group is studying further expansions of
ethylene production to be implemented over the coming years to meet its captive
and long-term customers' needs.
FAO also has a production capacity of 550,000 tonnes per year of chemical
grade propylene. This propylene, together with propylene from FRA, can be
transported by pipeline to various customers or to the Group for the production
of polypropylene, or stored in FAO's 10,000 tonne capacity propylene storage
terminal. Ethylene and other monomers from FAO are converted at the nearby Fina
Chemicals Antwerp facilities and at Fina Chemicals Feluy into high-density
polyethylene and thermoplastic elastomers.
FAO also produces aromatics, cyclohexane and other by-products which are
sold to the market or used by the adjacent refineries. The Group is also
planning to build a large aromatic extraction unit, fed by FRA, LOR and FAO.
Fina Chemicals Antwerp operates several high- and medium-density
polyethylene production lines in Antwerp and Feluy with a combined total
capacity as of December 31, 1997, of 450,000 tonnes per year, representing about
10% of the total installed capacity in Europe. Fina Chemicals Antwerp intends to
increase this capacity to 500,000 tonnes per year in 1998. Ethylene monomer is
received directly, via pipeline, from Fina Antwerp Olefins securing supply and
feedstock efficiencies for the Group. Antwerp's unique location, with its
excellent port facilities, access to pipelines and transportation networks and
its location in a large and dense industrial area enable it to serve customers
competitively with higher value-added products on a global basis. The Group's
polyethylene sales are focused on a few applications where it can supply
competitive products and services, such as pipes, blow molding, specialty films,
and wires and cables for the construction, packaging and automotive industries.
It has developed a metallocene catalyst technology which enables it to produce
promising medium-density grades for film applications, and it has other grades
under development.
Fina Chemicals Antwerp also operates a thermoplastic elastomer plant with a
capacity of 80,000 tonnes per year. The main applications are bitumen
modification for roofing and road applications, footwear, additives and plastic
modifications such as transparent food packaging. The Group is able to supply
these high value-added products competitively because of the plant's size and
its ability, through its technology, to use cheaper feedstocks.
Feluy. In March 1995, Fina Chemicals Feluy became a wholly owned
subsidiary of the Company as a result of the acquisition of the remaining 50%
interest from its former joint venture partner. Fina Chemicals Feluy owns a
polypropylene (homopolymer and propylene-ethylene copolymer) plant with two
production lines at Feluy which has a capacity of 400,000 tonnes per year, or
about 6% of total installed capacity in Europe. The Group has a project to build
a third polypropylene production line at this plant. In addition, in 1991 it
built a High Density Polyethylene ("HDPE") line with a capacity of 150,000
tonnes per year. The plant is supplied with ethylene and propylene by two
pipelines directly linked to the Group's chemical facilities in Antwerp.
PetroFina has fully utilized its capacity at this plant for several years.
Polypropylene is a widely used raw material for the manufacture of many commonly
used fibers, films, extrusion and injection applications and thermoformed
products, such as garden furniture and containers. The Group's sales of
polypropylene are focused on those applications in which it can supply
high-quality products and services and reach higher market share. It is also
developing partnerships with global customers that can be supplied from its U.S.
plants.
In March 1996, the Group sold its 50% interest in a polystyrene plant in
Feluy. Fina Chemicals Feluy continues to operate the plant with a capacity of
170,000 tonnes per year on behalf of the third party to whom PetroFina sold its
interest.
21
<PAGE> 24
Oleochemicals
Ertvelde and Oelegem. PetroFina produces oleochemicals (fatty acids, fatty
alcohols and glycerin and their derivatives such as esters, amines and
stearates) at its plants at Ertvelde near the port of Ghent and at Oelegem near
Antwerp.
The Group's Ertvelde and Oelegem plants have a combined production capacity
of 275,000 tonnes per year of fatty acids, fatty alcohols, glycerin, esters and
other derivatives. Oleochemicals, which are produced from renewable raw
materials, such as vegetable oils and animal fats, have a wide range of
applications including personal care products, detergents, cosmetics,
lubricants, drilling muds, plastic additives and pharmaceuticals. PetroFina's
fatty acids capacity is about 16% of the total effective capacity in Western
Europe. Its fatty alcohols plant utilizes the Group's proprietary technology
from which it can gain a competitive advantage over other fatty acid producers.
The Group's most recent developments include a range of high performance and
biodegradable grades, which are well positioned to benefit from the increasing
demand for both high performance and environmentally friendly products.
UNITED STATES
All of the Group's chemicals activities in the United States take place in
five plants located along the coast of the Gulf of Mexico. Each of these plants
produces either monomers or polymers.
Carville. At Carville (Louisiana) the Group has two plants: a fully
integrated polystyrene production plant and a 50% interest in the adjacent
Cos-mar monomer plant. The Group's plants in Carville reflect the Group's
strategy of achieving economies of scale through integration and through the use
of large-scale facilities.
The Cos-mar monomer plant is the world's largest styrene plant of its type.
The plant provides the Carville polystyrene plant with styrene for polystyrene
production. In turn, benzene from the Port Arthur refinery is used as a
feedstock to produce styrene. The Cos-mar plant recently was upgraded to
increase its production capacity to 950,000 tonnes per year. In 1997, 1996 and
1995 it operated at full capacity. The Group is in the process of developing a
new technology for monomer production at the Cos-mar plant, which has the
potential to lower both its capital and operating costs.
The Carville polystyrene plant is the world's largest single-site,
high-impact and crystal polystyrene plant with a capacity of 465,000 tonnes per
year. All the Group's U.S. polystyrene production is now concentrated in
Carville with 4 production lines, which are based on proprietary technology. The
most recent line began production in August 1996 and increased the Group's
annual capacity by 115,000 tonnes.
La Porte. The La Porte plant, located near Houston, Texas, is the world's
largest single-site polypropylene production plant, on the basis of capacity.
Major raw materials are supplied through 6 pipelines connected to various
refineries, steam crackers and propylene splitters. The plant produces bulk
homopolymers and random copolymers from 8 lines utilizing the Group's
proprietary technology. The plant's total polypropylene capacity is 680,000
tonnes per year. Its capacity was increased by 40% in 1995 following the start
up of the eighth production line. Capacity grew another 7% in 1996 following
several debottlenecking projects. Construction of a ninth line with block
co-polymer capability, which is scheduled to come on-line in the fourth quarter
of 1998, will increase, with other minor debottleneckings, total capacity to
over 975,000 tonnes per year. Its current capacity represents 12% of total
installed capacity in the United States. The plant operated at maximum capacity
in 1997, 1996 and 1995.
The Group has a one-third interest in a joint venture that owns and
operates a splitter plant at Mont Belvieu, Texas. The splitter upgrades
propylene from refinery grade into polymer grade in order to supply the La Porte
plant. This plant doubled its capacity following the introduction of a second
splitter in the summer of 1996 to 225,000 tonnes per year of polymer grade
propylene. The Group is constructing a third line/splitter and then will
debottleneck the first two splitters.
Bayport. The Bayport plant, in Texas, produces HDPE-grade polyethylene.
The Group acquired the plant in 1992, and its capacity has increased from
160,000 to 195,000 tonnes per year during the past four years. The Group has
decided to build a second line at the Bayport plant that will increase the
plant's annual capacity by an additional 200,000 tonnes. The second line is
expected to become operational in the fall
22
<PAGE> 25
of 1998. This new line will use the same technology as that which is currently
used at the Feluy and Antwerp plants, and will provide the Group with additional
commercial synergies with its European polyethylene production.
Port Arthur. In 1997, the Group signed a letter of intent with BASF
Aktiengesellschaft ("BASF") to build the world's largest liquid steam cracker
(the "Steam Cracker Joint Venture") adjacent to the Group's refinery located in
Port Arthur, Texas which will produce 820,000 tonnes of ethylene and 880,000
tonnes of propylene annually. On May 8, 1998, the Board of Directors of the
Company and the Board of Directors of BASF approved the Steam Cracker Joint
Venture.
PAINTS
The Sigma Coatings Group ("Sigma"), which is wholly owned by the Company,
consists of several companies that produce and sell paints and protective
coatings. Sigma has three principal divisions: decorative paints, marine and
anti-corrosion paints and industrial coatings.
Sigma's headquarters are in Amsterdam (the Netherlands), and it is active
principally in Belgium, Denmark, France, Germany, Italy, the Netherlands, Saudi
Arabia, the U.K. and the U.S. The main Sigma plants are located in the
Netherlands (Amsterdam, Uithoorn, Den Bosch), Belgium (Manage, Deurne), Germany
(Bochum), France (Valdoie), Saudi Arabia (Dammah), the U.K. (Buckingham,
Deeside) and the U.S. (Harvey, Louisiana).
The table below sets forth selected financial information for the Paints
segment for each of the years indicated.
<TABLE>
<CAPTION>
FOR THE YEAR ENDED
DECEMBER 31,
--------------------------------
1997 1996 1995
------ ------ ------
(IN MILLIONS OF BEF)
<S> <C> <C> <C>
Total operating revenue................................ 31,452 29,439 28,390
Inter-segment sales.................................... -- (3) --
Operating revenues to non-affiliates................... 31,452 29,436 28,390
Operating income....................................... 1,617 1,207 854
</TABLE>
Sigma's decorative paints are sold principally under the SIGMA, HISTOR,
NOVEMAIL, RAMBO and GAUTHIER brand names. Decorative paints, which account for
approximately 53% of Sigma's revenues, are sold primarily in Europe. Sigma is
one of the two largest producers of decorative paints in the Netherlands, the
second largest in Belgium and the fifth largest in western Europe (in each case
based on sales). In addition, the Group has a 20% interest in the largest
producer of decorative paints in Saudi Arabia and is responsible for the
management of that company, which markets the Sigma brand.
Sigma markets its marine paints worldwide and its anti-corrosion paints
primarily in Europe and also in the United States. Sales of marine and
anti-corrosion paints account for almost 26% of Sigma's revenues. Sigma is the
fifth largest producer of marine paints in the world based on sales.
Industrial coatings, which account for approximately 14% of Sigma's
revenues, are marketed primarily in Europe, although Sigma has licensed some of
its proprietary technology outside Europe. Sigma is the second largest European
producer of industrial coil coatings.
RESEARCH AND DEVELOPMENT
In 1997, the Group's research and development expenses amounted to BEF
3,230 million, compared to BEF 3,062 million in 1996 and BEF 2,883 million in
1995.
PetroFina conducts most of its research and development activities in its
three research centers located at Feluy (Belgium), La Porte (Texas) and
Amsterdam (the Netherlands). These research centers aim to improve the
production processes in the Group's refineries and chemical and paints plants,
as well as to develop new, more competitive products, applications and processes
and to provide technical assistance to
23
<PAGE> 26
customers. In recent years, research developments have resulted in advances in
the areas of desulphuration, special fuels, lubricants, polymers, oleochemicals
and paints.
PetroFina's research center at Feluy brings together on one site the
Group's main research and development activities in Europe, namely in refining,
catalysts, plastics, oleochemicals, fuels and lubricants. This centralization
enhances the coordination and integration of the research activities. The Feluy
research center is adjacent to one of PetroFina's major chemical manufacturing
plants, which enables the Group to integrate its research with operations. In
the United States, research and development activities covering the Group's
processes and products are consolidated in a research center located on-site at
the Group's La Porte chemical plant. The third research center is located in
Amsterdam where it is physically integrated with the Paints segment's main
production facility. This center specializes in paints and cooperates closely
with the Feluy research center.
OTHER MATTERS
COMPETITIVE, POLITICAL AND ECONOMIC FACTORS
There is strong competition both within the oil industry and with other
industries in supplying the energy needs of industry and consumers. The oil
industry is also particularly subject to regulation and intervention by
governments throughout the world in such matters as the award of exploration and
production interests; the imposition of specific drilling obligations;
environmental protection controls; price controls and transfer pricing
restrictions; control over the development, production rate and abandonment of a
field; restrictions, requirements or sanctions imposed on companies and their
products and services, because of, or with respect to, ownership, affiliations
or operations in certain foreign countries; and, possibly, nationalization,
expropriation or cancellation of contract rights. The oil industry is also
subject to the payment of royalties and taxation, which tend to be high compared
with those payable in respect of other commercial activities. Some of the
Group's oil reserves are located in countries outside Western Europe and North
America, certain of which individually may be considered politically and
economically unstable. Reserves recovery and the related operations are subject
to certain risks, including the establishment of export limits, the
renegotiation of contracts, the nationalization or renationalization of assets,
other risks relating to changes in local government regimes and policies and
resulting changes in business customs and practice, payment delays, currency
exchange restrictions and losses and impairment of operations due to actions of
insurgent groups. PetroFina attempts to conduct its business and financial
affairs in order to protect against such political and economic risks.
Although oil prices are primarily subject to international supply and
demand, political developments and the outcome of meetings at the Organization
of Petroleum Exporting Countries can also affect world oil supply and oil
prices. Crude oil prices are generally denominated in dollars while sales of the
Group's refined products are denominated in a variety of currencies. PetroFina
is, therefore, subject to the risks of fluctuations in exchange rates and crude
oil prices. It attempts to limit its short-term risks in these areas by engaging
in hedging and similar activities in the currency and oil commodity markets. For
additional information, see "Item 9A. Quantitative and Qualitative Disclosures
About Market Risk."
REGULATION OF UPSTREAM ACTIVITIES
PetroFina's exploration and production activities are conducted in a number
of different countries and are therefore subject to a broad range of legislation
and regulations. These cover virtually all aspects of exploration and production
activities, including matters such as land tenure, production rates, royalties,
pricing, environmental protection, export, taxes and foreign exchange. The terms
and conditions of the leases, licenses and contracts vary from country to
country. Outside the United States, these leases, licenses and contracts are
generally granted by or entered into with a government entity or state company,
while in the United States they are generally entered into with private property
owners. These arrangements usually take the form of licenses or production
sharing agreements.
Licenses (or concessions) give the holder the exclusive right to explore
for and exploit a commercial discovery. Under a license, the holder bears the
risks of exploration, development, and production activities and provides the
financing for these operations. A license holder is generally required to pay
production taxes
24
<PAGE> 27
or royalties, which may be in cash or in kind. In certain cases, the government
entity or state company may acquire a participation in the concession.
Production sharing agreements entered into with a government entity or
state company generally obligate the Group and its partners to provide all the
financing and bear the risk of exploration and production activities in exchange
for a share of the production remaining after royalties, if any. In some
instances, a fixed or variable percentage of this production is reserved for the
recovery of the Group's cost (cost oil) and the remainder (profit oil) is shared
with the government entity or state company on a fixed or volume-dependent
basis. The right of the Group to recover cost oil is limited in certain cases by
a requirement that the cost oil not exceed a maximum percentage of production.
This right is also limited in certain cases by a requirement that PetroFina's
costs be amortized over a specific period of time. In other cases, the
government entity or state company will participate in the rights and
obligations of PetroFina and will share in the costs of development and
production. Such participation can be across the venture or be on a per field
basis.
In certain countries, separate licenses are required for exploration and
production activities and, in certain cases, production licenses are limited to
a portion of the area covered by the exploration license. Both exploration and
production licenses are generally for specific periods of time (except for
production licenses in the United States which remain in effect until production
ceases). The term of the Group's licenses and the extent to which these licenses
may be renewed vary from area to area.
The Group is required in certain countries to relinquish a portion of the
acreage covered by a license as a condition to obtaining a renewal of the
license. The Group may also be required in certain countries to relinquish
acreage (or to surrender a license) under other circumstances. These
circumstances, which vary by area, may include the failure to obtain a
production license within a specified period of time or the failure to have a
field development plan approved within a specified period of time. PetroFina
believes that these requirements have not materially affected its operations.
In general, the Group is required to pay income tax on income generated
from production activities (whether under a license or production sharing
agreement). In addition, depending on the area, the Group's production
activities may be subject to a range of other taxes, levies and assessments,
including special petroleum taxes.
ENVIRONMENTAL MATTERS
The Group's operations are subject to laws and regulations of the EU,
Belgium, the United States and other countries in which it conducts activities
relating to the protection of the environment. These laws and regulations, which
change frequently, address the general impact of industrial operations on the
environment, as well as focus specifically on certain activities, including
emissions and toxic waste disposal. Environmental violations may result in
civil, criminal and tort liabilities.
Environmental factors are an important consideration in planning, designing
and operating all PetroFina facilities. A General Manager is responsible for the
coordination and implementation of environmental policies for the Company and
its subsidiaries. Each of the Company's subsidiaries conducts significant
programs to ensure that operations are carried out in an environmentally
acceptable manner. In 1997, 1996 and 1995 the Group spent over BEF 1.5 billion,
BEF 1.4 billion, and BEF 1.3 billion, respectively, on environmental programs
that included improving or constructing hydrodesulphuration units and hydrogen
plants at its refineries in order to comply with new EU fuel specifications,
construction of vapor recovery units at major depots, loading facilities and
service stations to meet EU requirements, as well as site restorations and
remediation activities.
Due to the nature of its business, environmental laws increasingly impact
PetroFina's operations and make some risk of environmental costs and liabilities
inherent to its business, as it is for other companies engaged in the same field
of activities. Although PetroFina's management is not aware of any conditions
that would result in a liability material to the Group as a whole, under
existing environmental laws there can be no assurance that such liabilities will
not be incurred. For additional information regarding environmental
25
<PAGE> 28
matters, see "Item 9. Management's Discussion and Analysis of Financial
Condition and Results of Operations -- Environmental Costs."
UNCERTAINTY INHERENT IN INDUSTRY
Oil and gas exploration and production, as well as PetroFina's refining and
chemical operations, require high levels of investment and have particular
economic risks and opportunities. These activities are subject to natural
hazards and other uncertainties, including those relative to the physical
characteristics of oil and gas fields, refineries and chemical plants.
LICENSING AND PROPRIETARY TECHNOLOGY
Licensing of PetroFina's proprietary technology relating to polystyrene,
thermoplastic elastomers, paints, dewaxing of diesel fuel and propylene
purification has increased significantly and now extends to countries such as
China, Japan, Taiwan, Korea and Saudi Arabia.
EMPLOYEE MATTERS
During 1997, the Group had an average of 14,675 employees. In recent years,
there have been no significant strikes or work stoppages. Information regarding
the Group's pension and benefit plans is contained in Note 19 of the Notes to
the Consolidated Financial Statements included in "Item 18. Financial
Statements."
PENDING TRANSACTION
On February 25, 1997, the Company proposed a merger transaction in which
the Company's U.S. subsidiary Fina, Inc. would become a wholly-owned affiliate
of the Company. The Company indirectly owns approximately 85% and 100% of the
Class A and Class B common stock of Fina, Inc., respectively. The transaction
initially proposed was a negotiated merger in which each holder of a Class A
share not owned by the Company and its affiliates would receive the equivalent
of US $60 per share in cash, PetroFina securities or a combination of cash and
PetroFina securities. Following receipt of the merger proposal, the Board of
Directors of Fina, Inc. appointed a special committee of independent directors
(the "Special Committee") to review and evaluate the merger proposal. The
Special Committee retained Cravath, Swaine & Moore as independent legal counsel
and Goldman Sachs & Co. as independent investment advisors to assist the members
of the Special Committee in carrying out their duties and responsibilities.
On February 17, 1998, the Company and Fina, Inc. entered into an Agreement
and Plan of Merger (the "Merger Agreement") pursuant to which New Fina, Inc., a
Delaware corporation and an indirect, wholly-owned subsidiary of the Company
will be merged (the "Merger") with and into Fina, Inc., and Fina, Inc. will be
the surviving corporation and (ii) each share of common stock of Fina, Inc.
outstanding immediately prior to the effective time of the Merger will be
converted into the right to receive (A) US $60 plus (B) one warrant (a
"PetroFina Warrant") to purchase nine-tenths of one PetroFina ADS. The PetroFina
Warrants will be exercisable for a period of five years from the date of the
Merger and will have an exercise price of US $42.25 per PetroFina ADS. Thus, a
holder of 10 PetroFina Warrants may purchase 9 PetroFina ADSs for an aggregate
purchase price of US $380.25. Also on February 17, 1998, the Special Committee
received an opinion from Goldman Sachs that the consideration to be received in
the Merger was fair from a financial point of view to the holders of the Common
Stock not affiliated with the Company. The Merger is subject to approval by a
majority of the stockholders of Fina, Inc. PetroFina has sufficient voting power
to cause the approval and adoption of the Merger Agreement without the
affirmative vote of any other stockholder of Fina, Inc.
PetroFina has filed a Registration Statement on Form F-4 with the U.S.
Securities and Exchange Commission to register the PetroFina Warrants under the
Securities Act of 1933, as amended. The Registration Statement contains
additional information about the background of the Merger and the opinion of
Goldman Sachs.
26
<PAGE> 29
The Company expects the Merger to be consummated on or before August 15,
1998.
If the transaction is consummated, the Company does not believe the
acquisition would have a material effect on the Group's financial condition or
results of operations.
Following the public announcement of the merger proposal, several
shareholders of Fina, Inc. filed separate lawsuits in the Court of Chancery of
the State of Delaware (the "Court") against the Company, Fina, Inc. and certain
directors of Fina, Inc. The lawsuits, which purport to be class actions, allege
a breach of fiduciary duties and seek to enjoin the merger or, if consummated,
to set it aside. The Company intends to contest the litigation vigorously. The
cases were consolidated into a single proceeding and stayed pending the
completion of negotiations between the Company and Fina, Inc. Following
negotiation and the voluntary production of documents to plaintiff's counsel,
plaintiffs and defendants in all of the consolidated actions entered into a
Memorandum of Understanding pursuant to which the action will be settled
contingent upon closing of the Merger and the entry of a final judgment
dismissing with prejudice all claims between plaintiff class members and the
defendants. On May 14, 1998, the parties submitted a Stipulation of Settlement
to the Court requesting a hearing to approve the settlement. The failure of the
Court to approve the settlement agreement will not affect the Merger which is
expected to occur prior to the scheduled hearing regarding approval.
ITEM 2. DESCRIPTION OF PROPERTY
See "Item 1. Description of Business" for a description of PetroFina's
principal plants and its reserves and sources of crude oil and natural gas.
ITEM 3. LEGAL PROCEEDINGS
PetroFina is involved in a number of legal proceedings incidental to the
normal conduct of its business. It does not believe that liabilities relating to
such proceedings are likely to be, in the aggregate, material to its
consolidated financial condition.
ITEM 4. CONTROL OF REGISTRANT
Based on the information provided in a Schedule 13G filed with the
Commission on February 13, 1998 (the "Schedule 13G"), the Company has set forth
below the number and percentages of PetroFina Shares owned by each person known
by the Company to own beneficially more than 10% of the outstanding PetroFina
Shares. Information in the notes to the table is also based on information in
the Schedule 13G.
<TABLE>
<CAPTION>
PERCENTAGE
NUMBER OF OF PETROFINA SHARES
SHAREHOLDER PETROFINA SHARES AND VOTING POWER
----------- ---------------- -------------------
<S> <C> <C>
Groupe Bruxelles Lambert S.A. and affiliated
companies(1)(2)(3)(4)..................................... 5,503,384 23.5%
Societe Generale de Belgique S.A. and affiliated
companies(1)(3)(5)........................................ 2,533,607 10.8%
Compagnie Nationale a Portefeuille(1)(3).................... 1,533,487 6.5%
</TABLE>
- ---------------
(1) GBL (and its affiliated companies), SGB (and its affiliated companies), S.A.
Fortis A.G. N.V. ("Fortis") (and its affiliated companies), and Sofina S.A.
("Sofina") may be deemed to be members of a group with respect to the
PetroFina Shares. Fortis and Sofina own 306,491 PetroFina Shares (1.3%) and
308,627 PetroFina Shares (1.3%), respectively. The number of PetroFina
Shares set forth next to each of GBL and SGB does not include PetroFina
Shares owned by each other, Fortis or Sofina.
(2) Includes 5,305,029 PetroFina Shares held by Electrafina, an affiliate of
GBL, and 198,355 PetroFina Shares held directly or indirectly by Royale
Belge S.A. ("Royale Belge"). On June 2, 1998, the Company was notified by
Royale Belge that Royale Belge is now controlled by Group AXA.
(3) CNP and GBL may be deemed to be members of a group with respect to the
PetroFina Shares owned by each of them. The number of PetroFina Shares set
forth next to each of GBL and CNP does not include
27
<PAGE> 30
PetroFina Shares owned by each other. CNP, on the one hand, and SGB, Sofina
and Fortis, on the other hand, have expressly disclaimed that they are
members of a group with respect to the PetroFina Shares beneficially owned
by each other. CNP has advised the Company that its shares are held by
FIBELPAR.
(4) Albert Frere, Chairman of the Company's Board of Directors, may be deemed to
control GBL and CNP.
(5) Includes 575,501 PetroFina Shares held by S.A. Tractebel N.V., 1,241,000
PetroFina Shares held by S.A. Electrabel N.V., 700,271 PetroFina Shares held
by S.A. Telfin N.V., 15,580 PetroFina Shares held by S.A. Contassur N.V. and
1,255 PetroFina Shares held by Beleggingsmaatschappij voor Noord-Belgie
(NOBEMA) N.V.
GBL and SGB have informed the Company of an agreement entered into in 1989
(the "1989 Agreement") in relation to their respective PetroFina Shares. In a
press release on March 8, 1989, they indicated that their common objective was
to provide the Company with long-term, stable shareholders and to support its
long-term strategy for the benefit of shareholders and staff generally. By
virtue of their ownership of PetroFina Shares and the 1989 Agreement, GBL and
SGB may be deemed to control the Company within the meaning of Rule 12b-2 under
the Securities Exchange Act of 1934, as amended.
The Company is aware that the 1989 Agreement was entered into by GBL and
SGB on behalf of themselves and their respective affiliates and, in the case of
SGB, on behalf of Fortis and Sofina and, in the case of GBL, on behalf of Royale
Belge S.A. and Generale des Eaux S.A. the Company is also aware that the 1989
Agreement contains provisions pursuant to which GBL and SGB have agreed to: (i)
limit their ownership of PetroFina Shares to 25% and 12.5%, respectively,
subject to certain exceptions; (ii) consult with each other on such matters as
the determination of strategic plans of the Company and its affiliates, changes
to the Articles, the issuance of PetroFina Shares, the incurrence of
indebtedness, significant acquisitions and dispositions, any takeover attempted
by a third party, dividend policy and the appointment of executive officers of
the Company; (iii) have representation on the Board of Directors proportional to
their ownership of PetroFina Shares, with GBL designating a director as Chairman
of the Company and SGB designating a director as a Vice-Chairman; and (iv) grant
each other a right of first refusal with respect to the PetroFina Shares if
either party decides to sell its PetroFina Shares. The Company understands that
the 1989 Agreement will continue until 2004. See "Item 10. Directors and
Officers of Registrant -- Board of Directors."
The Company is aware that its officers and directors as a group own at
least 16,000 PetroFina Shares. However, because the PetroFina Shares are held
partially in bearer form, the Company cannot identify precisely the number of
PetroFina Shares held by the officers and directors as a group. In addition,
certain directors of the Company, including Mr. Frere and Mr. Desmarais, Sr.,
are affiliates of the shareholders identified in the table above and could be
deemed beneficial owners of the PetroFina Shares identified in the table above.
See "Item 10. Directors and Officers of Registrant -- Board of Directors."
ITEM 5. NATURE OF TRADING MARKET
MARKET FOR PETROFINA SHARES
The principal trading market for the PetroFina Shares is the BSE in Belgium
where the PetroFina Shares are listed continuously on the Forward Market. In
1997, the PetroFina Shares were the most actively traded equity security on the
BSE. The PetroFina Shares are an important component of the Bel 20 Index, which
is a broad-based index of 20 of Belgium's significant, publicly traded
companies.
28
<PAGE> 31
The table below sets forth, for the periods indicated, the reported high
and low closing prices in Belgian francs for the PetroFina Shares on the BSE:
<TABLE>
<CAPTION>
PRICE PER
PETROFINA SHARE
(BEF)
---------------
HIGH LOW
---- ---
<S> <C> <C>
1995
First Quarter............. 9,510 7,990
Second Quarter............ 9,440 8,200
Third Quarter............. 9,240 8,560
Fourth Quarter............ 9,140 8,650
1996
First Quarter............. 9,480 8,220
Second Quarter............ 9,990 8,560
Third Quarter............. 10,250 9,230
Fourth Quarter............ 10,750 9,320
1997
First Quarter............. 12,800 10,050
Second Quarter............ 14,000 11,575
Third Quarter............. 15,600 13,150
Fourth Quarter............ 15,100 12,500
1998
First Quarter............. 14,375 12,525
</TABLE>
Official trading on the BSE is carried out using a fully-computerized order
matching system, the NTS (New Trading System). Securities are listed either on
the Forward Market which contains the largest and most liquid domestic and
foreign securities, or on the Spot Market, which contains small and midcap
companies. On the Forward Market, depending on the liquidity of the security in
question, listing takes place continuously from 10:00 am to 4:30 pm, Brussels
time, or semi-continuously with a double quotation at 10:15 am and 4:15 pm,
Brussels time. The PetroFina Shares are listed continuously on the Forward
Market. Settlements of securities listed on the Forward Market, based on a "Cash
on Delivery" system, take place at the end of a two-week period, the
"quinzaine," according to a fixed timetable.
The BSE is governed by a two-tier supervisory system: the Management
Committee of the BSE and the CBF. The Management Committee of the BSE, appointed
by members of the BSE, acts as an autonomous market authority, responsible for
the organization and the operation of the stock market. The CBF oversees the
activities of the BSE authorities and acts as a second-tier supervisory body
with respect to the market.
Transactions can be effected only by members of the BSE. Members include
credit or financial institutions, brokerage firms and members of other EU stock
exchanges.
The PetroFina Shares are also listed on the stock exchanges of Amsterdam,
Frankfurt, London and Paris and on the Swiss Stock Exchange and are quoted on
SEAQ International.
TRADING IN THE UNITED STATES
Citibank serves as depositary with respect to the PetroFina ADSs which have
traded on the NYSE since September 3, 1997 and in the OTC market in the United
States since 1990. Each PetroFina ADS represents one-tenth (0.1) of one
PetroFina Share. As of December 31, 1997 there were 607,000 PetroFina ADSs
outstanding (representing 0.26% of the outstanding PetroFina Shares), held by 15
registered PetroFina ADS holders. All such PetroFina ADSs were held by U.S.
residents. In addition, 6,985 registered PetroFina Shares (representing 0.03% of
the outstanding PetroFina Shares) are held by U.S. residents.
The table below sets forth, for the period indicated, the reported high and
low quotations in dollars for the PetroFina ADSs during the periods in which
they traded in the OTC market and the high and low closing sale
29
<PAGE> 32
prices for the PetroFina ADSs after September 3, 1997. The fourth quarter of
1997 represents the first full quarter of trading on the NYSE.
<TABLE>
<CAPTION>
PRICE PER ADS
(US$)
------------------
HIGH LOW
---- ---
<S> <C> <C>
1995
First Quarter......... 30.063 27.438
Second Quarter........ 32.563 28.438
Third Quarter ........ 30.781 28.359
Fourth Quarter........ 31.219 29.156
1996
First Quarter......... 31.609 26.984
Second Quarter........ 31.328 27.359
Third Quarter......... 32.297 29.547
Fourth Quarter........ 31.000 30.750
1997
First Quarter......... 35.500 31.250
Second Quarter........ 36.625 33.250
Third Quarter......... 39.375(1) 36.500(1)
39.500(2) 36.313(2)
Fourth Quarter........ 42.000 35.750
1998
First Quarter......... 38.000 33.375
</TABLE>
- ---------------
(1) Reflects trading prior to the NYSE listing on September 3, 1997.
(2) Reflects trading on the NYSE from September 3, 1997 through September 30,
1997.
ITEM 6. EXCHANGE CONTROLS AND OTHER LIMITATIONS AFFECTING SECURITY HOLDERS
EXCHANGE CONTROLS
Belgian exchange control regulations impose no limitations on the amount of
cash payments that may be remitted by the Company to residents of the United
States. However, when there is a transfer of funds by the Company an obligation
to notify the Institut belgo/Luxembourgeois du change/Belgisch-Luxemburgs
Wisselinstituut arises. If the transfer of funds is handled by Belgian financial
institutions, that institution will give the required notification. In addition,
the Company has arranged with a number of European and U.S. financial
institutions, including the Depositary, to handle such payments or transfers of
funds and make the required notification.
OWNERSHIP OF PETROFINA SHARES BY NON-BELGIAN PERSONS
Under Belgian law, if an individual or a company intends to acquire the
joint or exclusive control of the Company through one or more transactions
relating to the PetroFina Shares, the acquiror must notify the CBF of the
contemplated transaction at least five days before its completion. If the price
of the contemplated transfer includes a control premium, the acquiror must offer
to all other shareholders of the Company to be acquired the opportunity to sell
their PetroFina Shares at the highest price offered by the acquiror for
PetroFina Shares during the 12 months preceding the acquisition of control of
the Company. The acquiror must give the other shareholders this opportunity
within 30 days after its acquisition of control either (i) in the form of a
public takeover bid or (ii) pursuant to an undertaking to support the stock
price of the acquired company on the relevant stock exchange.
Public takeover bids must be made for all the outstanding voting securities
of the Company. Prior to making a bid, a bidder must issue a prospectus which is
approved by the CBF. Any bid made by or on behalf of either a non-EU national or
non-EU company is required to be approved by the Belgian Minister of Finance. In
case of a public takeover bid, the European Commission must approve the
transaction, if (i) the
30
<PAGE> 33
combined worldwide revenues of both the bidder and the Company to be acquired
exceed ECU 2,500 million, (ii) the combined revenues of the bidder and the
Company to be acquired in at least three EU member states exceed ECU 100
million, (iii) the revenues of each of the bidder and the Company to be acquired
from each of such three EU member states exceed ECU 25 million and (iv) the
total community-wide turnover of the bidder and the Company to be acquired
individually exceed ECU 100 million.
Public takeover bids are subject to the supervision of the CBF. If the CBF
determines that a takeover bid is contrary to the interests of the stockholders
of the Company, it may suspend the takeover bid for a maximum of 72 hours and
request the President of the Commercial Court in the district of the Company's
registered office (Brussels) to prohibit the bid and suspend the exercise of the
rights attached to any PetroFina Shares that were acquired in connection
therewith.
Under Belgian law, a company must notify the Minister for Economic Affairs,
the Minister of Finances, as well as the relevant Secretary of State for
regional Economy prior to any transaction which will transfer more than
one-third of the capital of a company that is located in Belgium and has equity
("fonds propres/eigen vermogen") in excess of BEF 100 million.
ITEM 7. TAXATION
UNITED STATES FEDERAL INCOME TAX CONSIDERATIONS RELATING TO PETROFINA ADSs
The following general discussion summarizes certain of the material U.S.
federal income tax consequences to U.S. Holders of the ownership, disposition or
exercise of PetroFina ADSs. The discussion considers only U.S. Holders that own
PetroFina ADSs as capital assets within the meaning of Code Section 1221.
The following discussion is based on current provisions of the Code,
current and proposed Treasury Regulations promulgated thereunder, administrative
and judicial interpretations as of the date hereof, and the U.S.-Belgium income
Tax Convention that entered into force October 13, 1972 as amended through the
Supplementary Protocol, signed on December 31, 1987 (the "Treaty"), all of which
are subject to change, possibly on a retroactive basis.
Except to the extent discussed below, the discussion does not consider the
U.S. tax consequences to a Non-U.S. Holder. This discussion of U.S. federal
income tax consequences does not purport to be a comprehensive description of
all of the tax considerations that may be relevant to a holder of PetroFina
ADSs, nor does it address the effect of any applicable foreign, state, local or
other tax laws. Further, the discussion does not consider holders that are
subject to special tax treatment, including dealers in securities, financial
institutions, insurance companies, tax-exempt organizations, persons subject to
the alternative minimum tax, current or prior holders (directly or indirectly)
of 10% or more of the voting shares of Parent, holders of securities held as
part of a "straddle," "hedge" or "conversion transaction," or U.S. Holders whose
"functional currency" (within the meaning of Section 985(b) of the Code) is not
the dollar. EACH HOLDER OF PETROFINA ADSs SHOULD CONSULT ITS OWN TAX ADVISOR AS
TO THE SPECIFIC TAX CONSEQUENCES OF OWNING, DISPOSING AND EXERCISING OF
PETROFINA ADSs.
In addition, this summary does not address the U.S. federal income tax
consequences were Parent determined to be a passive foreign investment company
("PFIC") for U.S. federal income tax purposes Generally, a PFIC is a foreign
corporation that has passive income that equals or exceeds 75% of its total
gross income or passive assets that represent at least 50% of its total assets
by fair market value. Parent does not believe it is currently, and does not
expect to become, a PFIC. U.S. Holders should consult their own tax advisors
concerning the U.S. federal income tax consequences of holding PetroFina ADSs if
the Company were considered to be a PFIC.
U.S. Holders
Ownership of PetroFina ADSs. In general, for U.S. federal income tax
purposes U.S. Holders of PetroFina ADSs will be treated as the owners of the
underlying PetroFina Shares. Distributions on PetroFina ADSs will constitute
dividends for U.S. federal income tax purposes to the extent of current and
accumulated earnings and profits of Parent as determined under U.S. federal
income tax principles. The dollar value of such
31
<PAGE> 34
dividends will be includible in the gross income of a U.S. Holder as ordinary
income on the day on which the dividends are received by the Depositary, without
reduction for any Belgian taxes withheld at source, and will not be eligible for
the dividends received deduction allowed to corporations under Section 243 of
the Code. For purposes of determining the dollar value of any distributions to a
U.S. Holder, distributions paid in Belgian francs will be converted into a
dollar amount calculated by reference to the exchange rate in effect on the day
they are received by the Depositary. U.S. Holders should consult their own tax
advisors regarding the treatment of foreign currency gain or loss, if any, on
any Belgian francs received which are not converted into dollars on the day the
Belgian francs are received by the Custodian.
To the extent, if any, that a U.S. Holder receives a distribution on
PetroFina ADSs that would otherwise constitute a dividend for United States
federal income tax purposes but that exceeds current and accumulated earnings
and profits of the Company, such distribution will be treated first as a
non-taxable return of capital reducing the U.S. Holder's basis in the PetroFina
ADSs. Any such distribution in excess of the U.S. Holder's basis in the
PetroFina ADSs will be treated as a capital gain.
Generally, U.S. Holders will have the option of claiming the amount of any
Belgian income taxes withheld on a dividend distribution to them as either a
deduction from gross income or, subject to the limitations described below, as a
dollar-for-dollar credit against their United States federal income tax
liability. A deduction or foreign tax credit will not be available with respect
to Belgian income taxes that may be refunded to a U.S. Holder pursuant to the
Treaty. A U.S. Holder that elects to deduct Belgian income taxes from gross
income may do so only for a taxable year in which the U.S. Holder claims a
federal income tax deduction with respect to all foreign income taxes.
Individuals who do not claim itemized deductions, but instead utilize the
standard deduction, may not claim the amount of the Belgian income taxes in
respect of distributions on the PetroFina ADSs as a deduction from their gross
income, but such amount may be claimed as a credit against the individual's
United States federal income tax liability. The amount of Belgian income taxes
for which U.S. Holders may claim a credit in any year is subject to certain
complex limitations and restrictions, which must be determined on an individual
basis by each U.S. Holder. The limitations set out in the Code include, among
others, new holding period requirements enacted pursuant to the Taxpayer Relief
Act of 1997 and rules under which foreign tax credits allowable with respect to
specific classes of income cannot exceed the United States federal income taxes
otherwise payable with respect to each class of income. Dividends paid by the
Company generally will be foreign source "passive income" (or, in the case of
certain holders, "financial services income") for United States foreign tax
credit purposes. Foreign income taxes exceeding the credit limitation for the
year of payment or accrual of such tax can be carried back for two taxable years
and forward for five taxable years, in order to reduce United States federal
income taxes subject to a credit limitation applicable in each of such years.
Other restrictions on the foreign tax credit include a limitation which
generally prevents use of the credit in any taxable year to reduce liability for
United States individual and corporate alternative minimum tax by more than 90%.
Holders should consult their tax advisors regarding limitations on the foreign
tax credit, including the new holding period requirements referenced above.
Disposition of PetroFina ADSs. Upon the sale, exchange or other
disposition of PetroFina ADSs, a U.S. Holder generally will recognize capital
gain or loss in an amount equal to the difference between such U.S. Holder's
basis in the PetroFina ADSs and the amount realized on the disposition. For
certain noncorporate U.S. Holders of PetroFina ADSs (including individuals), the
rate of taxation of capital gain will depend upon (i) the U.S. Holder's holding
period for the PetroFina ADSs (with the lowest rate available only for PetroFina
ADSs held more than 18 months) and (ii) the U.S. Holder's marginal tax rate for
ordinary income. U.S. Holders of PetroFina ADSs should consult their tax
advisors with respect to applicable rates and holding periods, and netting rules
for capital losses.
Gain realized by a U.S. Holder on a sale, exchange or other disposition of
PetroFina ADSs generally will be treated as U.S. source income for U.S. foreign
tax credit purposes. Under current law, the source of any loss on the sale,
exchange or other disposition of PetroFina ADSs is uncertain.
32
<PAGE> 35
Non-U.S. Holders
Further, subject to the discussion of backup withholding below, a Non-U.S.
Holder of PetroFina ADSs generally will not be subject to U.S. federal income
tax on gain realized on the sale of PetroFina ADSs or dividends received on
PetroFina ADSs unless (i) such gain is effectively connected with the conduct by
the Non-U.S. Holder of a trade or business in the United States and such
Non-U.S. Holder is not otherwise eligible for applicable treaty benefits or (ii)
in the case of gain realized by an individual Non-U.S. Holder, the Non-U.S.
Holder is present in the United States for 183 days or more in the taxable year
of the sale and certain other conditions are satisfied.
U.S. Information Reporting and Backup Withholding
Under certain circumstances, the Internal Revenue Service requires
"information reporting" and "backup withholding" at a rate of 31% with respect
to payments of dividends on PetroFina ADSs and the proceeds of disposition of
PetroFina ADSs. Subject to certain exceptions, information reporting and backup
withholding generally apply to U.S. Holders. A U.S. Holder will be subject to
backup withholding at a rate of 31% on payments of dividends on PetroFina ADSs
or the proceeds of disposition of PetroFina ADSs only if the U.S. Holder (i)
fails to provide a TIN on a properly completed W-9, (ii) furnishes an incorrect
TIN, (iii) is notified by the Internal Revenue Service that the U.S. Holder has
failed to properly report payment of dividends or interest, or (iv) fails, under
certain circumstances, to certify, under penalties of perjury, that it has
furnished a correct TIN. Backup withholding will not apply with respect to
payments made to certain exempt recipients, such as corporations and tax exempt
organizations.
The payment of the proceeds of the disposition of PetroFina ADSs by a
Non-U.S. Holder or the payment of dividends on PetroFina ADSs to or through the
U.S. office of a broker or through a non-U.S. branch of a U.S. broker generally
will be subject to information reporting and backup withholding at a rate of 31%
unless the holder either certifies its status as a Non-U.S. Holder under
penalties of perjury or otherwise establishes an exemption. The payment of the
proceeds of the disposition by a Non-U.S. Holder of PetroFina ADSs or the
payment of dividends on PetroFina ADSs to or through a non-U.S. office of a
non-U.S. broker will not be subject to backup withholding or information
reporting unless the non-U.S. broker has certain U.S. relationships.
Any amounts withheld under the backup withholding rules from a payment to a
Non-U.S. Holder will be refunded (or credited against the holder's U.S. federal
income tax liability, if any) provided that the required information is
furnished to the Internal Revenue Service.
CERTAIN BELGIAN INCOME TAX CONSIDERATIONS OF HOLDING AND DISPOSING OF PETROFINA
ADSs
Dividends -- U.S. Holder
In general, under Belgian law, the Belgian tax imposed on a dividend paid
to a non-resident that does not have a "permanent establishment" in Belgium will
be limited to the amount of the withholding tax, the current rate of which is
25%. This dividend withholding tax may be subject to reduction, however,
pursuant to income tax treaties that Belgium has entered into with other
countries. Pursuant to the Treaty, dividends paid by the Company to a U.S.
Holder that does not have a "permanent establishment" in Belgium generally will
be subject to a Belgian withholding tax at a reduced rate of 15%. Such
withholding is reduced, however, to 5% in the case of a corporation which owns
directly at least 10% of the Company's voting stock. Whether a Non-U.S. Holder
who is not a Belgian resident qualifies for a reduced rate of Belgian
withholding tax will depend upon whether such Non-U.S. Holder is a citizen or
resident of, or organized under the laws of, a country that has an income tax
treaty with Belgium that provides for a reduced rate of withholding tax and
whether the holder otherwise satisfies any conditions in the treaty necessary to
be eligible for the reduced rate of withholding tax.
Although there are exceptions, in general, the full Belgian withholding tax
must be withheld by the Company (that is, the amount of withholding upon the
payment of the dividend is not reduced to reflect the Treaty rate), and the U.S.
Holder may make a claim for reimbursement for amounts withheld in excess of the
33
<PAGE> 36
Treaty rate. The reimbursement form can be obtained from the Bureau Central de
Taxation Bruxelles-Etranger, Place Jean Jacobs, 10, B-1000 Brussels, upon
presentment of a form stamped by the U.S. Internal Revenue Service and the
document proving cashing of the dividend. The relevant form may be obtained from
the Depositary or Parent "Service a l'actionnaire," 52 Rue de l'Industrie,
B-1040 Brussels (Tel. +32-2-288.99.45/Fax +32-2-288.35.95). If the Forms 61,66
(U.S. IRS Certificate of Residence) and 276 (Belgian Ministry of Finance) are
properly completed and sent to the Depositary three working days prior to the
dividend payment date, the beneficial owner of the dividend will obtain the
reduced withholding tax rate at source. Prospective holders should consult their
own tax advisors as to whether they qualify for reduced withholding upon the
payment of dividends, and as to the procedural requirements for obtaining
reduced withholding upon the payment of dividends or for making claims for
reimbursement.
Under Belgian tax law the rate of the withholding tax can be reduced to 0%
in the case of dividends paid by a Belgian corporation to certain U.S.
organizations that are not engaged in any activity of a lucrative nature and
exempt from United States federal income tax. For instance, organizations either
constituted and operated exclusively to administer or provide pension,
retirement or other employee benefits or operated exclusively for religious,
charitable, scientific, educational or public purposes may qualify for the 0%
withholding tax rate. To benefit from this reduced rate, the qualified U.S.
Holders should sign a specific form, available by request from the "Service a
l'actionnaire" or included in the annual report, and send it back either to the
Depositary three working before the dividend payment date to obtain the reduced
withholding tax rate at source or to the "Directeur regional des contributions,
Bruxelles II-societes, avenue Louise 233-245, B-1050 Bruxelles" to be refunded
the excess withholding tax.
Dividends -- Non-U.S. Holder
As discussed above, Belgian tax law generally imposes a 25% withholding tax
on a dividend paid to a nonresident that does not have a "permanent
establishment" in Belgium. Whether a Non-U.S. Holder who is not a Belgian
resident qualifies for a reduced rate of Belgian withholding tax will depend
upon whether it is a resident of, or organized under the laws of, a country that
has an income tax treaty with Belgium that provides for a reduced rate of
withholding tax and whether the holder otherwise satisfies any conditions in the
treaty necessary to be eligible for the reduced rate of withholding tax.
Non-U.S. Holders entitled to a reduced withholding tax under a treaty may make
claim for reimbursements for overwithheld amounts. Reimbursement forms can be
obtained from the address listed in the discussion of "-- Dividends -- U.S.
Holders" above.
Capital Gains
U.S. persons and other non-residents of Belgium who do not have a permanent
establishment in Belgium will not be subject to Belgian income tax on the sale
or other disposition of PetroFina ADSs. Individual non-residents of Belgium with
a permanent establishment in Belgium will be subject to Belgian taxation on the
disposition of PetroFina ADSs, and such shareholders should consult their tax
advisors about the tax consequences to them of disposing of PetroFina ADS.
Estate and Gift Tax
A transfer of PetroFina ADSs by reason of death will be subject to Belgian
estate tax ("droits de succession/successierechten") only if the deceased had
his domicile or the seat of his estate in Belgium at the time of his death. The
estate tax shall be due on the whole estate of the deceased wherever the assets
are located.
A transfer of PetroFina ADSs by gift will be subject to a Belgian gift
registration tax ("droits d'enregistrement/registratierechten") only if it is
made through a notary deed in Belgian. A gift in bearer form does not have to be
made through a notary deed to be valid and effective. The registration tax
should not apply to gifts of PetroFina ADSs recorded in a notary deed that is
executed outside of Belgium.
34
<PAGE> 37
ITEM 8. SELECTED CONSOLIDATED FINANCIAL DATA
The following financial information with respect to the five years ended
December 31, 1997 has been derived from the Company's audited consolidated
financial statements. The audited consolidated financial statements for the
years ended December 31, 1997, 1996 and 1995 have been prepared in accordance
with generally accepted accounting principles in the United States ("U.S.
GAAP"). The consolidated financial statements for the periods ended December 31,
1994 and 1993, have been prepared in accordance with generally accepted
accounting principles in Belgium ("Belgian GAAP"). For purposes of the analysis
in "Item 9. Management's Discussion and Analysis of Financial Condition and
Results of Operations" certain balances related to 1994 have been adjusted to
provide an analytical basis for comparison to the 1996 and 1995 U.S. GAAP
presentation. The adjusted 1994 amounts are unaudited.
The information for the three years ended December 31, 1997, 1996 and 1995
should be read in conjunction with the consolidated financial statements and
notes included in "Item 18. Financial Statements."
PETROFINA S.A. AND SUBSIDIARIES
SUMMARY OF FINANCIAL AND OPERATING DATA
<TABLE>
<CAPTION>
U.S. GAAP BELGIAN GAAP
------------------------------------ -----------------------
FOR THE YEAR ENDED AND AT DECEMBER 31,
--------------------------------------------------------------
1997 1996 1995 1994 1993
---------- ---------- ---------- ---------- ----------
(IN BEF MILLION, EXCEPT PER SHARE DATA
AND NUMBER OF SHARES)
<S> <C> <C> <C> <C> <C>
FINANCIAL
Operating Revenue........................ 727,031 622,145 558,724 574,333 558,982
Depreciation, depletion and
amortization........................... 28,703 23,775 22,533 22,775 21,080
Exploration costs........................ 4,354 3,030 4,186 2,616 2,657
Operating Income......................... 46,833 39,388 30,788 27,744 20,411
Net earnings............................. 22,060 15,948 11,826 10,039 7,144
Net earnings per share................... 945 686 509 432 307
Cash dividends per share................. 400 352 320 280 280
Cash dividends per share (US$)(1)........ 11.44 11.07 10.83 8.22 8.33
Capital expenditures..................... 43,660 33,142 29,852 26,975 35,653
Long term obligations.................... 59,976 49,326 44,732 51,602 60,521
Total assets............................. 403,618 366,788 333,892 340,822 358,653
Stockholders' equity..................... 155,915 135,011 123,098 123,498 127,064
Average Shares outstanding............... 23,350,612 23,252,764 23,252,414 23,252,126 23,251,784
Ratio of earnings to fixed charges (%)... 6.21 5.27 4.19 3.53 2.35
OPERATIONS
Crude oil, condensate, and natural gas
liquids produced (in million barrels of
oil equivalent)........................ 52.2 49.3 50.7 42.8 34.5
Natural gas produced (in billion cubic
feet).................................. 208.9 210.7 204.0 211.7 228.5
Refinery throughput crude oil (thousand
barrels per day)....................... 669.0 645.3 597.8 593.8 551.4
Major chemicals and plastics produced (in
thousand tonnes)....................... 4,070 3,774 3,467 3,334 3,060
Employees (average for the year)......... 14,675 13,588 13,653 14,013 14,696
</TABLE>
- ---------------
(1) Based on the Noon Buying Rate on the first day dividends are available for
payment. See "Exchange Rates."
DIVIDENDS
PetroFina has paid dividends on the PetroFina Shares in each year for at
least the past 50 years. Future dividends will depend on the Company's earnings,
financial condition and other factors. The payment and amount of dividends are
subject to the recommendation of the Board of Directors and declaration by the
35
<PAGE> 38
Company's shareholders at the annual ordinary general shareholders' meeting. The
Company's Articles of Association provide that the Board of Directors may pay an
interim dividend as an advance against the annual dividend.
Dividends paid to holders of PetroFina ADSs will be subject to a charge by
the Depositary for any expenses incurred by the Depositary in the conversion of
Belgian francs to dollars. For a summary of certain United States federal and
Belgian tax consequences to holders of PetroFina Shares and PetroFina ADSs, see
"Item 7. Taxation."
The table below sets forth for the years indicated, the amount of dividends
paid per PetroFina Share.
<TABLE>
<CAPTION>
DIVIDEND DIVIDEND DIVIDEND
PER PER PER
PETROFINA PETROFINA PETROFINA
SHARE SHARE ADS
--------- --------- ---------
(BEF) (US $)(1) (US $)(2)
<S> <C> <C> <C>
1993...................................................... 280 8.33 0.838
1994...................................................... 280 8.22 0.940(3)
1995...................................................... 320 10.83 1.075
1996...................................................... 352 11.07 1.12
1997...................................................... 400 11.44 1.14
</TABLE>
- ---------------
(1) Based on the Noon Buying Rate on the first day dividends are available for
payment. See "Exchange Rates."
(2) Dividend paid by the Depositary per PetroFina ADS.
(3) Includes $0.129 paid to holders of Petrofina ADSs in connection with a
rights offering to holders of PetroFina Shares.
In May 1998, the Company paid a dividend of BEF 460 per PetroFina Share in
respect of the Company's 1997 earnings. Based on the Noon Buying Rate on May 27,
1998, the dollar equivalent of this dividend was US $12.52. On June 3, 1998, the
Depositary paid a gross dividend of US $1.25 per PetroFina ADS to all holders of
PetroFina ADSs as of May 20, 1998.
36
<PAGE> 39
ITEM 9. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
Overview
The information in this section should be read with the information
contained in PetroFina's consolidated financial statements and related notes
included in "Item 18. Financial Statements".
The consolidated financial statements for the years ended December 31,
1997, 1996 and 1995 have been prepared in accordance with U.S. GAAP. For
purposes of this analysis, certain balances related to 1994 have been adjusted
to provide an analytical basis for comparison to the 1996 and 1995 presentation.
The adjusted 1994 amounts are unaudited. See also "Item 8. Selected Consolidated
Financial Data."
Certain information contained in this Registration Statement, including,
without limitation, information appearing under "Item 1. Description of
Business," "Item 9. Management's Discussion and Analysis of Financial Condition
and Results of Operations," and "Item 9A. Quantitative and Qualitative
Disclosures About Market Risk" are forward-looking statements. The following
important factors, together with others that appear with the forward-looking
statements, could affect the Group's actual results and could cause the Group's
actual consolidated results to differ materially from those expressed in any
forward-looking statements made by, or on behalf of, the Group in this Annual
Report. PetroFina's operating results are generally affected by a variety of
factors, including movements in crude oil prices and refining and chemical
margins and currency exchange rates. Higher crude oil prices generally have a
positive effect on operating income of the Group, as its Upstream oil and gas
business benefits from the resulting increase in prices realized from
production. Lower crude oil prices generally have a corresponding negative
effect. See "Item 1. Description of Business -- Upstream -- Reserves." The
effect of changes in crude oil prices on PetroFina's Downstream activities
depends upon the speed at which the prices of refined petroleum products adjust
to reflect such changes. Fluctuations of the Belgian franc against other
currencies, especially the dollar, can have significant effects on PetroFina's
consolidated financial statements. Prices for crude oil are normally set in
dollars. Chemical products are generally priced in local currency but based, in
Europe, on German mark ("DEM") benchmark prices. Generally, the Group's
operating income is improved by a strengthening of the dollar and major European
currencies against the Belgian franc. In addition, the effects of translation of
local currency financial statements of PetroFina's non-Belgian subsidiaries can
influence comparative results of operations. See also "Item 9A. Quantitative and
Qualitative Disclosures About Market Risk."
37
<PAGE> 40
RESULTS OF OPERATIONS
The following table sets forth certain financial data for the Group as a
whole for the periods indicated.
<TABLE>
<CAPTION>
FOR THE YEAR ENDED DECEMBER 31,
---------------------------------
1997 1996 1995
------- ------- -------
(IN BEF MILLION EXCEPT PER SHARE
DATA AND NUMBER OF EMPLOYEES)
<S> <C> <C> <C>
CONSOLIDATED DATA
Operating Revenue........................................... 727,031 622,145 558,724
Earnings from investments, equity interests................. 1,386 1,466 1,345
Total revenue.......................................... 728,417 623,611 560,069
======= ======= =======
Operating Income............................................ 46,833 39,388 30,788
Interest and net financial items............................ (4,596) (5,066) (5,171)
------- ------- -------
Earnings before income taxes and minority interests......... 42,237 34,322 25,617
Income taxes................................................ (19,531) (17,678) (13,092)
Minority interests.......................................... (646) (696) (699)
------- ------- -------
Net income.................................................. 22,060 15,948 11,826
Earnings per share.......................................... 945 686 509
Dividend per share.......................................... 400 352 320
Average number of employees................................. 14,675 13,588 13,653
</TABLE>
SEGMENT DATA
<TABLE>
<CAPTION>
CORPORATE
& OTHER
UPSTREAM DOWNSTREAM CHEMICALS PAINTS ACTIVITIES CONSOLIDATED
-------- ---------- --------- ------ ---------- ------------
(IN BEF MILLION)
<S> <C> <C> <C> <C> <C> <C>
1997
Operating Revenue................. 88,265 571,964 93,247 31,452 478 785,406
Inter-segment Sales............... (36,298) (16,961) (5,116) (58,375)
Operating Revenue from Non
Affiliates...................... 51,967 555,003 88,131 31,452 478 727,031
Operating Income (Loss)........... 25,288 12,005 10,439 1,617 (2,516) 46,833
Capital Expenditures.............. 23,016 10,092 8,983 1,014 555 43,660
1996
Operating Revenue................. 65,212 496,361 78,404 29,439 1,033 670,449
Inter-segment Sales............... (31,123) (13,757) (3,421) (3) -- (48,304)
Operating Revenue from Non
Affiliates...................... 34,089 482,604 74,983 29,436 1,033 622,145
Operating Income (Loss)........... 24,165 5,195 11,337 1,207 (2,516) 39,388
Capital Expenditures.............. 17,964 8,971 3,687 1,151 1,369 33,142
1995
Operating Revenue................. 48,598 441,688 79,941 28,390 1,319 599,93
Inter-segment Sales............... (21,687) (16,448) (2,744) -- (333) (41,212)
Operating Revenue from Non
Affiliates...................... 26,911 425,240 77,197 28,390 986 558,724
Operating Income (Loss)........... 13,400 235 19,014 854 (2,715) 30,788
Capital Expenditures.............. 12,288 7,818 7,993 745 1,008 29,852
</TABLE>
38
<PAGE> 41
GROUP RESULTS 1997 VS. 1996
In 1997, net income reached a record level of BEF 22.1 billion (945 BEF per
share) compared to BEF 15.9 billion (686 BEF per share) in 1996, representing an
increase of 39%. The Group's return on equity was 15.2% in 1997 compared to
12.4% in 1996. The return on capital employed increased in 1997 to 10.5% from
8.9% in 1996.
Consolidated Cash Flow, defined as consolidated net income adjusted for
depreciation and other current year non-cash provisions to net income, was BEF
57.1 billion compared to BEF 44 billion in 1996. The 1997 consolidated cash flow
also represents a record for the Group.
Compared to 1996, the increase in consolidated net income reflects a BEF
7.4 billion improvement in Group operating income combined with lower financial
charges resulting from higher capitalization of interest on Upstream development
projects. Of the 1997 increase in operating income, BEF 6.8 billion is related
to Downstream from higher margins and throughputs at the Group's European and
North American refineries. Upstream operating income improved by BEF 1 billion
as increases in production and the dollar appreciation overcame the effect of
lower crude oil prices. Chemicals operating income decreased by BEF 1 billion
due primarily to the unfavorable net effect of North American product price
decreases. Paints operating income showed improvement of BEF 400 million in 1997
compared to 1996.
The Group's consolidated operating revenue in 1997 was BEF 727.0 billion,
an increase of 17%, or BEF 105 billion, from the previous year. Of the increase,
BEF 32 billion is the result of appreciation of the dollar and other European
currencies versus the Belgian franc, BEF 20 billion reflects increases in sales
volumes, BEF 25 billion is related to higher sales prices, and BEF 29 billion
reflects increases in petroleum product excise duties.
During 1997, reductions in the statutory tax rates in Italy and the United
Kingdom resulted in a reduction of total income tax expense of BEF 1.3 billion
through the recording of a deferred tax credit (in accordance with US GAAP).
Excluding this effect of tax rate changes, the Group's effective tax rate was
49.3% in 1997 compared to 51.5% in 1996. The lower effective tax rate reflects
the improvement in Downstream operating income. As a result, a lower percentage
of Group earnings before tax is attributable to Norwegian production activities.
Norwegian production activities carry a higher tax burden due to specific
petroleum tax legislation in Norway.
UPSTREAM
<TABLE>
<CAPTION>
1997 1996 1995
--------------------- --------------------- ---------------------
NORTH NORTH NORTH
EUROPE(1) AMERICA EUROPE(1) AMERICA EUROPE(1) AMERICA
---------- -------- ---------- -------- ---------- --------
(IN BEF MILLION EXCEPT NUMBER OF EMPLOYEES, PRODUCTION AND RESERVES)
<S> <C> <C> <C> <C> <C> <C>
Operating Revenue(2)................ 49,077 39,188 41,960 23,252 34,731 13,867
Equity in Net Income of Non-
Consolidated Investees............ 690 86 892 -- 484 48
------- ------- ------- ------- ------ -------
Total Revenue.................. 49,767 39,274 42,852 23,252 35,215 13,915
Operating Expense, Excluding
Depreciation
and Exploration Expense........... (14,932) (31,706) (10,599) (17,444) (9,519) (10,946)
Depreciation........................ (8,289) (3,464) (6,605) (2,320) (6,899) (1,778)
Exploration Expense................. (2,203) (2,151) (1,775) (1,255) (2,680) (1,506)
Other Operating Expense............. (990) (18) (1,877) (64) (2,276) (126)
------- ------- ------- ------- ------ -------
Operating Income (Loss)............. 23,353 1,935 21,996 2,169 13,841 (441)
======= ======= ======= ======= ====== =======
Capital Expenditures................ 15,250 7,766 12,945 5,019 9,801 2,487
Total Assets........................ 65,346 30,342 57,702 22,703 48,174 18,007
======= ======= ======= ======= ====== =======
</TABLE>
39
<PAGE> 42
<TABLE>
<CAPTION>
1997 1996 1995
--------------------- --------------------- ---------------------
NORTH NORTH NORTH
EUROPE(1) AMERICA EUROPE(1) AMERICA EUROPE(1) AMERICA
---------- -------- ---------- -------- ---------- --------
(IN BEF MILLION EXCEPT NUMBER OF EMPLOYEES, PRODUCTION AND RESERVES)
<S> <C> <C> <C> <C> <C> <C>
Crude Oil Production (in million
barrels)(3)....................... 48 4 45 4 47 4
Natural Gas Production (in Bcf)..... 132 77 152 59 150 54
Proved Oil Reserves (in million
barrels)(3)....................... 510 73 485 77 515 35
Proved Gas Reserves (in Bcf)........ 1,188 400 1,349 393 1,428 337
Total Proved Reserves (in
million barrels of oil
equivalent)(4)............... 708 139 710 142 753 91
======= ======= ======= ======= ====== =======
Average Number of Employees......... 345 493 372 453 413 476
======= ======= ======= ======= ====== =======
</TABLE>
- ---------------
(1) Europe includes Europe and other parts of the world outside North America.
(2) Includes inter-segment revenue.
(3) Excluding equity affiliates.
(4) 1 barrel of oil equivalent = 1 barrel of crude oil = 6,000 cubic feet of
gas.
OPERATING REVENUE
Operating revenue in 1997 was BEF 88.3 billion compared to BEF 65.2 billion
in 1996, an increase of 35%. Increases in production volumes and gas marketing
activities contributed BEF 11.9 billion to the overall increase. The
appreciation of the dollar and other European currencies versus the Belgian
franc resulted in an additional BEF 11.7 billion increase in reported operating
revenue. Decreases in worldwide crude prices were primarily offset by higher
North American natural gas prices. The net effect of price developments during
1997 resulted in a BEF 0.5 billion reduction in operating revenue compared to
1996.
In Europe, operating revenue increased 17% to BEF 49.1 billion in 1997.
Crude oil production in 1997 was 48.2 million barrels, an increase from 1996 of
3.0 million barrels, while natural gas production in 1997 was 132.3 billion
cubic feet, a decrease from 1996 of 19.6 billion cubic feet. The operating
revenue included revenues derived from 29 billion cubic feet of gas trading.
Reported operating revenue from Europe benefitted in 1997 from the appreciation
of the dollar by 16% and the British pound by 21% against the Belgian franc.
Realized crude oil prices dropped $1.95 per bbl to $18.96 per bbl.
Of the production increase in Europe, 3,900 barrels per day was due to the
drilling of new wells in connection with the Ekofisk II redevelopment project in
Norway. An additional 5,000 barrels per day of the total production increase was
attributable to a full year's production from the Thelma field and increased
flows from the Alba field after a successful de-bottlenecking project. Natural
gas production in Europe decreased by 19.6 billion cubic feet, due mainly to
Norway. In the United Kingdom, natural gas production was stable. Increases
resulting from the production start of the Armada and Everest fields and from a
re-determination of ownership percentages for the Audrey field were offset by a
reduction in natural gas production from Hewett and the Ann/Alison fields.
In North America, operating revenue increased 68% to BEF 39.2 billion in
1997. Natural gas volumes sold, which include production and volumes sold
through the Group's natural gas marketing activity, increased from 183 billion
cubic feet in 1996 to 281 billion cubic feet in 1997. Of the volume increase,
17.8 billion cubic feet related to natural gas production increases is
attributable to successful step-out drilling programs at core properties in
South Texas and North Louisiana. Natural gas well-head prices increased from
$2.41 in 1996 to $2.57 per thousand cubic feet in 1997. Although crude
production was level between the periods, the average crude oil well-head price
decreased by $1.40 per barrel to $17.90 per barrel. Both operating revenue and
operating income include a gain on sale of assets amounting to BEF 0.3 billion
in 1997.
40
<PAGE> 43
OPERATING INCOME
Upstream operating income was BEF 25.3 billion in 1997 compared to BEF 24.2
billion in 1996, an increase of 4%. The increase was due to operating revenue
developments partially reduced by the effect of lower margins realized in North
America on natural gas marketing activity and an increase in exploration costs.
In 1997, PetroFina participated in the drilling of 27 exploration wells
compared to 29 wells in 1996. Approximately 55% of wells drilled originated from
existing discoveries of oil and gas reserves, thus allowing for the better
evaluation of existing prospects. PetroFina's weighted average working interest
in exploratory wells drilled was 40.4% in 1997 compared to 29.4% in 1996.
In Europe, operating income was BEF 23.4 billion compared to BEF 22.0
billion in 1996, an increase of 6.4%. The depletion rate of US $3.06 per barrel
(on a units-of-production basis) was largely unchanged in 1997 versus 1996. The
impact of gradually commissioning Ekofisk II facilities, and downward revisions
of Ann/Alison reserves (-17.6 billion cubic feet) were virtually absorbed by the
impact of positive revisions in the estimated Norwegian reserves. The downward
revision in Ann/Alison's recoverable reserves resulted in an impairment
writedown in Ann/Alison capitalized cost of BEF 0.5 billion. Lifting costs have
decreased to US $4.05 per barrel in 1997 from US $4.29 per barrel in 1996 due to
greater efficiencies in production facilities.
Exploration expenses for Europe amounted to BEF 2.2 billion in 1997
compared to BEF 1.8 billion in 1996.
In North America, operating income was BEF 1.9 billion in 1997 compared to
BEF 2.2 billion in 1996. The decrease in operating income mainly reflects higher
dry hole expenses and lower natural gas marketing margins, partially offset by
positive net developments in operating revenues. The increase in development
costs and the downward revision in oil and gas reserves have led to an increase
in the unit depletion rate (unit of production method) from US $5.19 per barrel
in 1996 to US $5.79 per barrel in 1997. Lifting costs have decreased from US
$4.20 per barrel in 1996 to US $3.53 per barrel in 1997. The drilling program in
1997 resulted in additions to reserves of 18 million barrels of oil equivalent,
thereby allowing 121% of production to be replaced.
41
<PAGE> 44
DOWNSTREAM
<TABLE>
<CAPTION>
1997 1996 1995
-------------------- ---------------------- -------------------
NORTH NORTH NORTH
EUROPE(1) AMERICA EUROPE(1) AMERICA EUROPE(1) AMERICA
--------- -------- --------- ------- --------- -------
(IN BEF MILLION EXCEPT NUMBER OF EMPLOYEES,
REFINING THROUGHPUT AND PRODUCTS SOLD)
<S> <C> <C> <C> <C> <C> <C>
Operating Revenue(2)............. 462,637 109,327 402,943(3) 93,418 360,654 81,034
Equity in Net Income of Non-
Consolidated Investees......... 744 (2) 814 3 600 1
-------- -------- -------- ------- -------- -------
Total Revenue............... 463,381 109,325 403,757 93,421 361,254 81,035
Operating Expense, Excluding
Depreciation................... (442,851) (103,741) (387,763) (90,946) (352,468) (78,046)
Depreciation..................... (8,633) (2,203) (7,258) (1,879) (6,518) (2,080)
Other Operating Expense.......... (2,467) (806) (3,039) (1,098) (1,920) (1,022)
======== ======== ======== ======= ======== =======
Operating Income (Loss).......... 9,430 2,575 5,697 (502) 348 (113)
======== ======== ======== ======= ======== =======
Capital Expenditures............. 8,397 1,695 6,625 2,346 6,572 1,246
Total Assets................ 145,419 49,607 141,749 43,168 136,636 36,868
======== ======== ======== ======= ======== =======
Refining Throughput (in thousand
barrels per day)............... 445 224 441 205 384 213
Refined Product Sold (in thousand
tonnes)........................ 26,161 12,540 25,278 12,016 24,367 12,378
======== ======== ======== ======= ======== =======
Average Number of Employees...... 5,452 1,233 4,475 1,161 4,705 1,196
======== ======== ======== ======= ======== =======
</TABLE>
- ---------------
(1) Europe includes Europe and other parts of the world outside North America.
(2) Includes inter-segment revenue.
(3) Includes capital gains on sales of assets of BEF 973 million.
OPERATING REVENUE
Downstream operating revenue in 1997 was BEF 572.0 billion compared to BEF
496.4 billion in 1996, an increase of 15%. Increases in European petroleum
product prices more than offset reductions in North American realized prices,
leading to a net increase in operating revenue in 1997 of BEF 18 billion. The
appreciation of the US dollar and other European currencies versus the Belgian
franc resulted in an additional BEF 19 billion of reported operating revenue.
Increases in product sales volumes, shop sales and service station revenues
contributed the remainder of the 1997 increase. In addition, excise duties,
which do not affect Group operating income, increased by BEF 29.0 billion in
1997 compared to 1996. Total petroleum products sold increased by 4% to 38.7
million tonnes in 1997 compared to 1996.
In Europe, operating revenue increased by 15% to BEF 462.6 billion in 1997
compared to BEF 402.9 billion in 1996. Excluding the effect of higher excise
duties, the increase was BEF 34 billion. Of this net increase, BEF 22 billion
related to increased product prices, BEF 7 billion related to the reporting
effect of currency exchange rate fluctuations, BEF 4 billion related to
increases in quantities sold, and BEF 2 billion related to other operating
revenues. 1996 operating revenue included BEF 1 billion of gain on the disposal
of assets.
In North America, the operating revenue was BEF 109.3 billion in 1997
compared to BEF 93.4 billion in 1996. Appreciation of the dollar against the
Belgian franc contributed BEF 12 billion to the increase in reported operating
revenue, increases in quantities sold contributed BEF 3 billion, and higher
excise duties added BEF 3 billion. A decrease in average sale prices of
petroleum products resulted in a BEF 4 billion reduction in operating revenue
compared to 1996. Shop sales and other operating revenue grew during 1997 by BEF
2 billion.
42
<PAGE> 45
OPERATING INCOME
Downstream operating income was BEF 12.0 billion in 1997 compared to BEF
5.2 billion in 1996. The growth in operating income is due to better refining
performances, increased margins on European petroleum product sales, and the
appreciation of the dollar versus the Belgian franc.
In Europe, Downstream refining throughput reached 445,310 barrels per day
in 1997 compared to 440,550 barrels per day in 1996. The 1997 refining
throughput was a new record for the Group and was accomplished despite a
temporary shutdown of the Killingholme refinery in the United Kingdom for
scheduled maintenance. Higher throughput and advantageous blending of crude oil
feedstocks had a direct effect on Downstream operating income. The Group
estimates that standard refining margins in northern European refineries
increased on average US $0.10 per barrel to US $2.42 per barrel in 1997. The
average refining margin for the Group's Europe refining activity grew by $0.56
per barrel in 1997.
Marketing operating income in Europe improved in all countries where the
Group operates with the exception of Norway, which remained adversely affected
by severe price competition. Network sales have improved by 3% while the market
growth was 1% on average during 1997. In accordance with the Group's marketing
strategy, the Group restructured the management arrangements for a number of
sales outlets which brought the stations under direct Group management. The
reduction in management fees and the increase in non-fuel shop margins more than
offset the resulting increase in personnel expenses.
In North America, 1996 was characterized by very low industry-wide Gulf
Coast refining margins. In 1997, Gulf Coast refining margins improved which,
together with record throughput volumes at the Group's North American
refineries, resulted in improved refining yields and performance. Compared to
1996, Gulf Coast refining margins increased by $0.80 per barrel for the
industry. The Group's average refining margins increased by US $1.17 per barrel
in 1997. Throughput in 1997 reached 223,700 barrels per day, a record high for
the Group. Throughput in 1996 was 204,700 barrels per day and was affected by
two temporary refinery shutdowns for scheduled maintenance.
The increased operating income from refining operations was partially
absorbed by losses incurred in the supply business resulting from lower crude
oil prices and by a decrease in Marketing margins caused by lower North American
product prices.
43
<PAGE> 46
CHEMICALS
<TABLE>
<CAPTION>
1997 1996 1995
------------------- ------------------- -------------------
NORTH NORTH NORTH
EUROPE(1) AMERICA EUROPE(1) AMERICA EUROPE(1) AMERICA
--------- ------- --------- ------- --------- -------
(IN BEF MILLION EXCEPT NUMBER OF EMPLOYEES AND VOLUMES
PRODUCED)
<S> <C> <C> <C> <C> <C> <C>
Operating Revenue(2)............. 55,687 37,560 46,567 31,837 49,371 30,570
Equity in Net Income/Loss of
Non-Consolidated Investees..... (152) (35) 7 (22) 359 (18)
------- ------- ------- ------- ------- -------
Total Revenue............... 55,535 37,525 46,574 31,815 49,730 30,552
Operating Expense, Excluding
Depreciation................... (45,714) (31,600) (38,940) (23,204) (35,822) (20,849)
Depreciation..................... (3,207) (1,238) (2,999) (999) (2,881) (701)
Other Operating Expense.......... (528) (334) (451) (459) (589) (426)
======= ======= ======= ======= ======= =======
Operating Income................. 6,086 4,353 4,184 7,153 10,438 8,576
======= ======= ======= ======= ======= =======
Capital Expenditures............. 3,230 5,753 1,947 1,740 4,604 3,389
Total Assets................ 37,513 30,931 35,712 22,489 35,893 17,076
======= ======= ======= ======= ======= =======
Monomer Production
(in thousand tonnes)........... 1,241 659 1,123 610 1,124 550
Polymers Production
(in thousand tonnes)........... 899 1,271 880 1,161 888 905
======= ======= ======= ======= ======= =======
Average Number of Employees...... 1,920 913 1,876 932 1,811 894
======= ======= ======= ======= ======= =======
</TABLE>
- ---------------
(1) Europe includes Europe and other parts of the world outside North America.
(2) Includes inter-segment revenue.
OPERATING REVENUE
Operating revenue for the Chemicals segment increased by 19% to BEF 93.2
billion in 1997 from BEF 78.4 billion in 1996. For substantially all of the
Group's product range, record production volumes were achieved. As a result,
quantities of monomers and polymers sold increased by 6%, or BEF 6 billion, in
1997. Exchange rate fluctuations increased reported operating revenue by BEF 5
billion. Average sales price developments, particularly for European monomer
products, contributed BEF 4 billion to the increase. 1996 operating revenue
included a gain on sales of assets amounting to BEF 0.3 billion.
In Europe, operating revenue increased by BEF 9.1 billion to BEF 55.7
billion in 1997, representing a 19.5% increase from 1996. The Group experienced
price increases and volume increases within practically its entire range of
monomer and polymer products. Monomer price developments, while still below 1995
levels, were positive in 1997 with price increases experienced both for ethylene
and propylene.
In North America, operating revenue increased by 18% to BEF 37.6 billion in
1997. Excluding the effect on operating revenue from the appreciation of the US
dollar, the increase was 3%. Sales volumes increased by 9.5% to contribute BEF 3
billion to operating revenue in 1997 versus 1996. However, sales prices declined
by 7% in the same period, adversely affecting comparable 1997 operating revenue
by BEF 2 billion. North America styrene prices dropped to the lowest level since
1993 due primarily to the impact of new production coming on-line during the
year.
OPERATING INCOME
Chemicals operating income was BEF 10.4 billion in 1997 compared to BEF
11.3 billion in 1996, or a decrease of 8%. Increased plant efficiency due to
higher production volume, increased European monomers (ethylene and propylene)
margins and increased contribution from higher sales quantities were more than
offset by the impact of reduced polymers margins and lower North American
styrene margins.
44
<PAGE> 47
In Europe, operating income was BEF 6.1 billion in 1997 compared to BEF 4.2
billion in 1996. The improved performance is essentially linked to monomers,
which have benefited from price stability of raw materials while experiencing
some restoration in the sales price for ethylene and propylene. For polymer
products, sales prices also increased in 1997, but to a lesser extent and were
not sufficient to offset the increase in monomer prices. Monomers are the
principal raw material for polymer production.
In North America, operating income was BEF 4.4 billion in 1997, which is
39% below the 1996 operating income of BEF 7.2 billion. Unfavorable product
price developments in North America more than offset the economies of scale
realized at the Group's plants from higher production volumes. Sales volumes
have grown by 9% but margins decreased by 50% due to both unfavorable price
developments from increased industry capacity coming on-stream and increases in
raw materials prices. The impact of declining margins was partially negated by
the reporting effect of the appreciation in the dollar versus Belgian franc.
PAINTS
<TABLE>
<CAPTION>
1997 1995 1996
---- ---- ----
(IN BEF MILLION EXCEPT NUMBER OF
EMPLOYEES)
<S> <C> <C> <C>
Operating Revenue(1)........................................ 31,452 29,439 28,390
Equity in Net Income of Non-Consolidated Investees.......... 24 20 15
======= ======= =======
Total Revenue.......................................... 31,476 29,459 28,405
Operating Expense, Excluding Depreciation................... (28,403) (26,673) (25,982)
Depreciation................................................ (914) (830) (838)
Other Operating Expense..................................... (542) (749) (731)
======= ======= =======
Operating Income............................................ 1,617 1,207 854
======= ======= =======
Capital Expenditures........................................ 1,014 1,151 745
Total Assets................................................ 19,706 18,717 17,813
======= ======= =======
Average Number of Employees................................. 3,822 3,878 3,706
======= ======= =======
</TABLE>
- ---------------
(1) Includes inter-segment revenue.
OPERATING REVENUE
Paints operating revenue was BEF 31.5 billion in 1997 compared to BEF 29.4
billion in 1996, an increase of 7%. This increase was the result of higher sales
volumes, contributing BEF 1.4 billion, and the effect of exchange rates on
reported operating revenues, contributing BEF 0.5 billion. The increase in
operating revenue is related mainly to the Marine, Anti-corrosion and Industrial
sectors. The Decorative paints sector, while experiencing variations in
development in different countries, overall experienced slightly higher
operating revenue in 1997 compared to 1996.
OPERATING INCOME
Operating income was BEF 1.6 billion in 1997 compared to BEF 1.2 billion in
1996. In both years, the operating income of Paints includes the direct costs of
redevelopment activities for the Decorative paints sector, principally in France
and Germany. The increase in 1997 operating income is the result of improved
production capacity utilization, improved margins emanating from lower raw
material costs, and from reductions in operating costs resulting from the
redevelopment activities. The above improvements were partially offset by a
write-off of BEF 130 million for plant closure decisions in Germany and in
Denmark.
45
<PAGE> 48
GROUP RESULTS 1996 VS. 1995
Group operating revenue for 1996 increased 11% to BEF 622,145 million, up
from BEF 558,724 million in 1995. This BEF 63.4 billion improvement is primarily
attributable to several factors including: BEF 43 billion due to an increase in
petroleum product selling prices; BEF 11 billion due to the appreciation of the
dollar and several European currencies against the Belgian franc; BEF 7 billion
related to sales volume increases in all operating segments; a decline of BEF 12
billion as selling prices in the chemical sector decreased compared to 1995
levels and an increase of BEF 12 billion related to a rise in duties and excise
taxes. Group operating income in 1996 rose 28% to BEF 39,388 million over 1995's
level of BEF 30,788 million.
In 1996, crude oil prices reached their highest level in five years.
European refining margins improved in 1996 after being depressed since 1993. The
combined effects of higher energy prices and improved European refining margins
along with improving plant operational performances lifted Upstream and
Downstream operating results in 1996. The chemicals industry reached a high
point in its market cycle in the first half of 1995 followed by a downturn in
the second half of 1995 and 1996. In 1996, the Group's main Chemical products
showed a progressive improvement in prices, supported by strong demand. However,
the extent of this price movement was not enough to offset an increase in raw
material costs.
The stronger Upstream and Downstream prices and stronger foreign currencies
against the Belgian franc contributed to both operating revenue and operating
income increases in 1996 compared to 1995 and reduced the effects of weaker
industry margins for the United States' Chemicals segment.
Earnings before taxes and minority interests in 1996 amounted to BEF 34,322
million compared to BEF 25,617 million in 1995, an increase of 34%. The
improvement was primarily due to the increase in Group operating income.
Interest expenses decreased slightly as a result of interest capitalization on
the Ekofisk II redevelopment program. See also "Item 1. Description of
Business -- Upstream." Equity in net earnings from non-consolidated subsidiaries
also increased in 1996 as a result of the restoration of oil production in
Angola. Other items were substantially unchanged between the two years.
UPSTREAM
OPERATING REVENUE
Operating revenue in 1996 for the Upstream segment was BEF 65,212 million,
reflecting a 34% increase compared to BEF 48,598 million in 1995. Increases in
crude oil and natural gas prices in 1996 contributed BEF 5.6 billion and BEF 7.7
billion respectively to this improvement. The appreciation of the dollar against
the Belgian franc resulted in BEF 2.9 billion of additional operating revenue.
The Group's production and gas trading activities were relatively stable. While
total crude oil production declined 3%, natural gas production rose 3%.
In Europe, Upstream operating revenue improved 21% as a result of advances
in crude oil prices and the strengthening of the dollar against the Belgian
franc. During 1996, the average price per barrel was US $4.10 higher than in
1995 while the dollar appreciated 5% against the Belgian franc. Production was
relatively stable. Crude oil production decreased about 3% while natural gas
production grew slightly more than 1%. In Norway, both oil and gas production
declined slightly. Natural gas production in the United Kingdom increased
because natural declines in the output from older fields were offset by
increased production from newer gas fields.
In North America, Upstream operating revenue increased over 67% as a result
of growth in crude oil and natural gas prices and the appreciation of the dollar
against the Belgian franc. North American average wellhead crude oil prices
increased 24%, or US $3.75 per barrel, while natural gas sales prices rose 62%
in 1996 compared to 1995. Total production sales volumes went up 8%, due to
increased natural gas production. Gas marketing activities contributed an
additional US $0.52 per thousand cubic feet in 1996 compared to US $0.18 per
thousand cubic feet in 1995. Gas marketing activity allows the Group to move
large quantities of equity and third party natural gas to areas with premium
pricing.
46
<PAGE> 49
OPERATING INCOME
Upstream operating income was BEF 24,165 million in 1996 compared to BEF
13,400 million in 1995, an improvement of 80%. This increase was due to
increased prices and the strengthening of the dollar and major European
currencies against the Belgian franc.
In Europe, operating income increased 59% as a result of higher operating
revenue. Operating expense decreased slightly in 1996 compared to 1995 despite
the strengthening of foreign currencies against the Belgian franc. Exploration
expense decreased slightly as a result of the Group's emphasis during the year
on proven areas and an improvement in the rate of successful wells drilled.
Depreciation per barrel decreased from US $3.32 in 1995 to US $3.07 in 1996.
This decrease was due to upward revisions in proved reserves for certain
producing fields which decreased the units-of-production rate of depreciation.
Lifting costs were US $4.29 per barrel oil equivalent in 1996 against US $4.43
in 1995.
In North America, the improvement in operating income was primarily the
direct result of favorable price developments and a stronger dollar. North
American lifting costs per barrel of oil equivalent remained relatively stable.
Total North American operating expense excluding depreciation increased due to
the effect of stronger natural gas prices on quantities purchased from third
parties for resell by the Group's gas marketing activity.
PetroFina participated in 29 gross exploratory wells in 1996 compared to 26
in 1995. Approximately 61% of the wells completed in 1996 either discovered new
potential reserves of crude oil or natural gas or upgraded existing discoveries,
compared to 46% in 1995. PetroFina's participation interest in net exploratory
wells was 29.4% in 1996 compared to 14.9% in 1995.
DOWNSTREAM
OPERATING REVENUE
Downstream operating revenue increased 12% in 1996 to BEF 496,361 million
compared to BEF 441,688 million in 1995. Higher prices for petroleum products
contributed BEF 35.6 billion to the increase in revenue; BEF 11.3 billion
related to a rise in duties and excise taxes; and BEF 7.8 billion resulted from
the appreciation of the dollar and several principal European currencies against
the Belgian franc. Quantities sold in 1996 were consistent with levels achieved
in 1995.
In Europe, operating revenue increased by approximately 18% in 1996,
excluding the effect of larger excise taxes and duties. Of this increase, 80%
was due to increased petroleum product prices. Operating revenue also increased
in 1996 because of higher sales volumes and the appreciation of European
currencies against the Belgian franc. Changes in excise taxes and duties do not
affect Downstream's operating income.
In North America, operating revenue increased by about 17% in 1996,
excluding the effect of increasing excise taxes and duties. The growth in
operating revenue was caused by conditions similar to those experienced in
Europe. Petroleum product prices caused about 84% of the increase. Operating
revenue, as reported in Belgian francs, also improved as a result of a stronger
dollar which was partially offset by lower sales volumes. United States refinery
throughput in 1996 decreased by 4%.
OPERATING INCOME
The Downstream segment produced operating income of BEF 5,195 million in
1996 compared to BEF 235 million in 1995. This large increase in operating
income was due to petroleum product price increases and improved European
refinery margins.
In Europe, the Group's refining throughput increased by 15% in 1996
compared to 1995. In 1996, refinery throughput reached 440,550 barrels per day
to establish a record volume for the Group. European industry margins were US
$2.27 per barrel in 1996 compared to US $1.80 per barrel in 1995. The margin
improvement was the result of favorable price differentials between gas oil and
fuel oil. The average price differential for these products increased from US
$64 per tonne in 1995 to US $107 per tonne in 1996. Retail margins remained
relatively stable in 1996 compared to 1995. Negative effects of retail price
wars in the United
47
<PAGE> 50
Kingdom and Norway were offset by improved performances in other European
markets. In 1996, the Group's retail sales increased by 6% while the average
sales per site increased by 11%.
In North America, 1996 was characterized by low industry wide Gulf Coast
refinery margins combined with a 4% reduction in the Group's refinery
throughput. The throughput reductions resulted from scheduled major turnaround
activities at both United States refineries. Aromatics margins, particularly
important for the Port Arthur refinery, were at their lowest level in five years
and 40% below 1995. Despite negative pricing developments, North American
refining operations maintained competitive per barrel costs and yields in 1996.
In retail, branded marketing margins decreased less than 1% in 1996 while total
volumes grew 1%, and market share in key markets increased.
CHEMICALS
OPERATING REVENUE
Operating revenue for the Chemicals segment declined 2% to BEF 78,404
million in 1996 from BEF 79,941 million in 1995. In the first half of 1995, the
industry realized the benefits of high prices and profit margins for all
monomers and polymers. In the second half of 1995 (particularly in the fourth
quarter), the industry faced a substantial product price decrease. In 1996,
product prices stabilized, despite increasing demand.
A decline in overall sales prices resulted in a decrease of BEF 11.2
billion which was substantially offset by an increase in quantities sold of BEF
8.5 billion, and by a BEF 1.4 billion increase from the appreciation of the
dollar against the Belgian franc.
In Europe, operating revenue decreased by 6% as a result of lower product
sales prices partially offset by increased sales quantities. Weighted average
realized prices for monomers decreased 13% in 1996 compared to 1995. Prices for
main polymers decreased by 15% while polymer sales volumes increased.
Polypropylene sales volume increased by 17% and polyethylene sales volume by 5%
compared to 1995.
In North America, operating revenue increased by 4%. Price developments
during 1996 for polypropylene and polyethylene were similar to those in Europe
but the weighted average price realized for styrenics products fell
substantially lower by 20%. Total chemical sales volumes were up 25% versus the
prior year reflecting the higher production levels resulting from completion of
major expansion projects at the North American polypropylene and polystyrene
plants. See "Item 1. Description of Business -- Chemicals."
OPERATING INCOME
Chemicals operating income was BEF 11,337 million in 1996 compared to BEF
19,014 million in 1995, a decrease of 40%. The decrease reflected lower weighted
average sale prices in 1996 compared to 1995. Operating income also decreased
due to 1996 increases in raw material costs for crude oil and related products.
Negative industry price developments were partially offset by total sales volume
increases of 10% in 1996 compared to 1995. The production volume increases were
the result of the acquisition of the remaining 50% of Fina Chemicals Feluy plant
in Belgium in March 1995, major expansion projects at the North American
polypropylene and polystyrene plants and, to a lesser extent, other plant
optimization programs. In February 1996, the Group sold its European polystyrene
production facilities, resulting in a reduction in annual production capacity of
55,000 tonnes.
In Europe, operating income in 1996 amounted to BEF 4,184 million compared
to BEF 10,438 million in 1995, a 60% decrease. The 1996 decrease in operating
income was a reflection of the industry's margin developments as raw material
cost increases, especially for monomers, were not reflected in finished goods
pricing.
In North America, operating income in 1996 amounted to BEF 7,153 million
compared to BEF 8,576 million in 1995, a reduction of 17%. The reduction in
operating income was smaller than in Europe due to the relatively lower
importance of monomers as an end sales product. Operating income was also
positively
48
<PAGE> 51
affected by additional cost efficiencies from greater economies of scale
resulting from larger production capacity. Production efficiencies were
partially offset by increases in gas price and raw materials costs.
PAINTS
OPERATING REVENUE
Operating revenue for the Paints segment in 1996 amounted to BEF 29,439
million compared to BEF 28,390 million in 1995, an improvement of 4%. During
1996, the paint industry continued a consolidation trend which began in late
1994 resulting in increasing globalization and competition. The industry's
growth occurred mainly in Asia. In Europe, the markets for industrial coatings
and decorative paints were weaker reflecting the weakness in the construction
market in Germany and France, offset slightly by decorative paints sales
increases in the Benelux countries. Paint's main sales growth was due to
positive market developments influencing both price and quantities sold in the
marine and anti-corrosion product sector.
OPERATING INCOME
Operating income in 1996 amounted to BEF 1,207 million compared to BEF 854
million in 1995, an increase of 41%. In all of Paint's product sectors, the
Group was able to improve profit margins through cost reductions. Paints'
operating income in 1996 included commercial development expenditures incurred
in France and Germany to enhance the Group's market position in the decorative
paint sector and other non-recurring charges of BEF 190 million.
IMPACT OF INFLATION AND CHANGING PRICES
The Group's operations are not seasonal but are sensitive to crude oil and
natural gas pricing, margins between crude oil and refined products, and
chemicals margins. These factors are beyond the Group's ability to influence and
are the result of global market developments. In the past, crude oil, natural
gas and product prices have fluctuated in response to market and political
forces. Oil and natural gas prices are also influenced by regional factors such
as regional supply, alternative fuel costs, and weather. See also "-- Financial
Instruments."
The general rate of inflation in most major countries where the Group
operates has been relatively low in recent years. Associated impacts on
operating costs have been countered by cost reductions from productivity
improvements. Inflation has not been a factor influencing production and product
pricing. Inflation does affect the cost of acquiring replacement property,
plants and equipment. The replacement cost of property, plants and equipment is
generally greater than the historical cost as a result of inflation. To a
certain degree, the effect of inflation on replacement costs is countered by
cost reductions due to improved technologies and applied knowledge.
LIQUIDITY AND CAPITAL RESOURCES
OVERVIEW
PetroFina defines "Cash Flow," for purposes of its Belgian financial
reporting, as consolidated net income adjusted for depreciation and other
current year provisions to net income. Because "Cash Flow" as so defined
excludes the effect of changing working capital items, it is different from Cash
Flow provided by operating activities as reported in the Consolidated Statements
of Cash Flows. See "Item 18. Financial Statements -- Consolidated Statements of
Cash Flows."
Cash Flow amounted to BEF 57,142 million, BEF 43,965 million and BEF 39,660
million in 1997, 1996 and 1995, respectively. The increase in Cash Flow of BEF
13.2 billion in particular reflected the increase in net income of BEF 6.1
billion, the appreciation of the dollar and several European currencies of BEF
2.6 billion, the increase of Depreciation, Depletion and Amortization mainly due
to the Upstream sector of BEF 3.1 billion and an increase in net deferred tax
liabilities of BEF 1.5 billion.
49
<PAGE> 52
Cash provided by operating activities was BEF 53,926 million, BEF 36,819
million and BEF 37,848 in 1997, 1996 and 1995, respectively. Cash provided by
operating activities in 1996 was reduced in relation to 1995 by the effects of
increasing working capital accounts.
Capital expenditures, which include investment in affiliates and
exploration expenses, amounted to BEF 43,660 million, BEF 33,142 million and BEF
29,852 million in 1997, 1996 and 1995, respectively.
Net cash used in financing activities was BEF 10,999 million, BEF 8,015
million and BEF 9,366 million in 1997, 1996 and 1995, respectively. Dividend
payments have progressively increased with net income and amounted to BEF 9,301
million, BEF 8,185 million and BEF 7,441 million in 1997, 1996 and 1995,
respectively. Net cash provided by operating activities (BEF 53.9 billion) and
the warrant exercise proceeds (BEF 2.1 billion), allowed the financing of
capital expenditures of BEF 43.7 billion, the payment of a dividend of BEF 9.3
billion and the net reimbursement of the financial debt of 3.2 billion.
Consolidated stockholders' equity was BEF 155,915 million, BEF 135,011
million and BEF 123,098 million at the end of 1997, 1996 and 1995, respectively.
The Group's ratio of interest-bearing debt to equity was 53% at the end of 1997,
compared to 60% at the end of 1996 and 62% at the end of 1995.
CAPITAL AND EXPLORATION EXPENDITURES
Capital and exploration expenditures in 1997 were BEF 43.7 billion compared
to BEF 33.1 billion in 1996 and BEF 29.9 billion in 1995. These expenditures
included capitalized interest of BEF 1.6 billion in 1997, compared to BEF 0.9
billion and BEF 0.4 billion in 1996 and 1995, respectively. Of the 1997
capitalized interest amount, BEF 1.4 billion related to Upstream.
Upstream capital expenditures amounted to BEF 23 billion in 1997 an
increase of 28% from BEF 18 billion in 1996. Upstream expenditures in 1995
represented 12.3 billion. European capital and exploration expenditure amounted
to BEF 15.3 billion compared to BEF 12.9 billion in 1996 while North American
expenditure amounted to BEF 7.8 billion and BEF 5.0 billion in 1997 and 1996,
respectively. The largest expenditures related to the Ekofisk II redevelopment
activities, while BEF 3.6 billion and BEF 5.7 billion were spent for various
field development activities in the UK and North America, respectively. The
remainder was principally incurred in exploration activities. Of the total
exploration expenditure of BEF 4.6 billion in 1997, BEF 2.9 billion was
expensed.
Downstream capital expenditures in 1997 totaled BEF 10.1 billion compared
to BEF 9.0 billion in 1996 and BEF 7.8 billion in 1995. An amount of BEF 5.0
billion reflected an increase in expenditures devoted to the extension and
enhancement of the Group's marketing network in Europe.
Chemicals capital expenditures were BEF 9.0 billion in 1997 compared to BEF
3.7 billion in 1996 and BEF 8.0 billion in 1995. Polymer production expansion
programs, particularly in North America, totaled BEF 4.5 billion in 1997.
The 1998 capital expenditure budget is currently estimated to be BEF 46.6
billion which is allocated as follows: BEF 19 billion for Upstream, BEF 12
billion for Downstream, BEF 13.5 billion for Chemicals and BEF 2.1 billion for
Paints and other activities.
YEAR 2000
During 1996, the Group developed a plan to deal with the Year 2000 issue
and began converting its computer systems to be Year 2000 compliant. The plan
provides for the conversion efforts to be completed during 1999. The Year 2000
issue is the result of computer programs being written using two digits rather
than four to define the applicable year. The Year 2000 costs are being funded
through operating cash flow and are not expected to be material in relation to
the Group operating results. The Group is expensing all costs associated with
these systems modifications as the costs are incurred.
50
<PAGE> 53
OUTLOOK
ENVIRONMENTAL COSTS
PetroFina is engaged in industrial operations that are subject to
environmental risks. In this context, the Group is subject to changing
environmental laws and regulations which may in the future require the Group to
meet more stringent emissions standards or take remediation actions for
contaminated sites.
The Group has accrued BEF 9.6 billion as of December 31, 1997 related to
the estimated costs of site restorations and remediation activities. Accruals
are established when the Group determines that events have occurred which
require remediation under existing laws and regulations related to plants or
other facilities, currently owned or previously disposed. Due to inherent
uncertainties of the estimation process and the background of changing laws and
regulations, it is reasonably possible that provisions will be subject to
revision. In addition, new conditions related to PetroFina's operations that
would require future expenditures could be discovered. The amount of such future
costs is not determinable due to the unknown existence and extent of corrective
actions that may be necessary.
The Group's recent major capital expenditure programs in its Downstream and
Chemicals segments over the past five years have been carried out with due
consideration to the requirements of existing and expected legal and regulatory
environmental developments regarding air and water emissions as well as
compliance with the EU's Stage I vapor recovery requirements at major depots,
loading facilities and service stations.
The EU's Stage II vapor recovery requirements, currently under discussion,
would place stringent obligations at all petrol service stations within the EU.
In certain countries, where the majority of the Group's European retail
operations are located, legislation has already been passed requiring compliance
of all newly built and certain categories of existing stations.
The Group's new service station building programs and station rebuilding
programs have been designed to enable the station to comply with future Stage II
requirements with minimal additional costs or to provide current compliance
where necessary.
At certain older stations, the cost of Stage II compliance is not
considered justifiable. Current and future legislation will result in closure of
a number of stations for the Group and for most of its competitors. The Group
has assessed the implication of current legislation and the potential impact of
enactment in those countries not yet affected. The Group believes that any
effect would not be material to the Group's competitive market position, nor
materially affect the Group's consolidated financial position, results of
operations or cash flows.
ITEM 9A. Quantitative and Qualitative Disclosures About Market Risk
INTEREST RATE SENSITIVITY
The tables below provide information about PetroFina's financial
instruments that are sensitive to interest rate changes. These include long-term
debt and interest rate swaps. For long-term debt, the table presents principal
cash flows and the average interest rates related to these cash flows per
expected maturity date, after currency swap effects. For interest rate swaps,
the table presents for the five coming years and thereafter the nominal contract
amounts by expected maturity date and the weighted average of the interest rates
related to these amounts. Nominal amounts are used to calculate the contractual
payments to be exchanged under the contracts. Weighted average variable rates
are based on implied forward rates of the yield curve on December 31, 1997. The
information is presented in BEF equivalent, which is PetroFina's reporting
currency. Cash Flows are denominated in various currencies, as indicated in
parentheses.
51
<PAGE> 54
EXPECTED MATURITY DATE ON DECEMBER 31, 1997
<TABLE>
<CAPTION>
TOTAL
NOMINAL FAIR
1998 1999 2000 2001 2002 THEREAFTER VALUE VALUE
----- ----- ------ ----- ------ ---------- ------- ------
(BEF EQUIVALENT IN MILLIONS)
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Long Term Debt
-- Fixed Rate (US$)............... 2,565 2,188 2,048 5,709 1,086 3,846 17,442 18,356
Average Interest Rate............... 7.14% 6.97% 7.02% 6.97% 7.35% 7.82%
-- Fixed Rate (BEF)............... 18 17 9,699 4 9,738 10,534
Average Interest Rate............... 8.39% 8.84% 8.84%
-- Fixed Rate (Other)............. 40 143 285 30 13 235 746 759
Average Interest Rate............... 8.01% 10.09% 7.31% 10.28% 9.73% 0.73%
-- Variable Rate (US$)............ 1,846 13,131 13,499 28,476 28,476
Average Interest Rate............... 5.74% 5.8% 5.83%
-- Variable Rate (NOK)............ 368 368 368 368 2,211 3,683 3,683
Average Interest Rate............... 3.83% 3.83% 3.83% 3.83% 3.83%
-- Variable Rate (NLG)............ 86 86 86 86 3,707 4,051 4,051
Average Interest Rate............... 3.58% 3.58% 3.58% 3.58% 3.81%
-- Variable Rate (Other).......... 59 59 59 59 59 151 446 457
Average Interest Rate............... 4.69% 4.69% 4.69% 4.69% 4.69% 4.69%
----- ----- ------ ----- ------ ------ ------ ------
-- Total Long Term Debt (including
current portion of long term
debt)........................... 4,528 2,861 12,545 6,252 14,743 23,653 64,582 66,316
===== ===== ====== ===== ====== ====== ====== ======
</TABLE>
The above table presents long term debt after the effects of PetroFina's
currency swaps which convert 284 million equivalent of BEF of Spanish peseta
("ESP")-denominated debt into dollar-denominated debt and 3,683 million
equivalent BEF of US $ denominated debt into Norwegian krone ("NOK")-denominated
debt. The "Other" category includes debt denominated in various other European
currencies which currently exhibit a high degree of correlation.
EXPECTED MATURITY DATE ON DECEMBER 31, 1997
<TABLE>
<CAPTION>
TOTAL
NOMINAL FAIR
1998 1999 2000 2001 2002 THEREAFTER VALUE VALUE
----- ----- ---- ----- ----- ---------- ------- -----
(BEF EQUIVALENT IN MILLIONS)
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Interest Rate Swaps
-- Variable to Fixed (US$)............ 1,846 1,846 1,846 3,323 15,061 23,922 (918)
-- Average Pay Rate................... 7.09% 7.64% 6.36% 7.68% 6.94%
-- Average Receive Rate............... 5.87% 6.01% 6.05% 6.13% 6.16%
Fixed to Variable (US$)................. 137 72 114 5,324 1,484 1,361 8,492 165
-- Average Pay Rate................... 5.91% 5.95% 6.06% 6.11% 6.12% 6.12%
-- Average Receive Rate............... 5.76% 5.76% 5.76% 6.81% 6.27% 6.71%
----- ----- ---- ----- ----- ------ ------ ----
Total Interest Rate Swaps............. 1,983 1,918 114 7,170 4,807 16,422 32,414 (753)
===== ===== ==== ===== ===== ====== ====== ====
</TABLE>
PetroFina tries to use the most cost-effective means to fund the Group's
operating and capital needs. Fixed or variable debt will be borrowed in various
currencies. To manage risk arising from fluctuations in interest rates and
currency exchange rates, and therefore maintain the efficient debt mix,
PetroFina utilizes currency and interest rate swaps.
After currency and interest rate swaps, approximately 60% of PetroFina's
long-term debt is fixed rate debt. The main currencies of denomination of this
fixed long-term debt are Belgian francs and United States dollars. Approximately
70% of the fixed long-term debt is denominated in dollars, 69% of the long-term
debt is dollar debt and 66% of the variable rate debt is also denominated in
dollars.
52
<PAGE> 55
Due to the current currency mix of the PetroFina debt, the Group is exposed
to changes in short term U.S. interest rates. However, it is widely believed
that this does not pose a significant risk as a substantial portion of the
Group's cash flows are generated by U.S. subsidiaries or by dollar-related
activities, which are positively correlated to the changes in short-term U.S.
interest rates.
EXCHANGE RATE SENSITIVITY
The table below provides information about PetroFina's financial
instruments by functional currency and presents such information in Belgian
franc equivalent. The table summarizes information on instruments that are
sensitive to foreign currency exchange rates, including foreign currency
denominated debt and currency swap agreements. For debt obligations, the table
presents principal cash flows and related weighted average interest rates by
expected maturity dates. For currency swap agreements, the table presents the
nominal amounts and weighted average exchange rates by expected (contractual)
maturity dates. These nominal amounts generally are used to calculate the
contractual payments to be exchanged under the contract.
EXPECTED MATURITY DATE
<TABLE>
<CAPTION>
TOTAL
NOMINAL FAIR
1998 1999 2000 2001 2002 THEREAFTER VALUE VALUE
---- ---- ---- ---- ------ ---------- ------- -----
(BEF EQUIVALENT IN MILLIONS)
<S> <C> <C> <C> <C> <C> <C> <C> <C>
On-balance Sheet
GBP (pound sterling) Functional Fixed
Rate (ESP)............................ 63 63 63 63 32 284 313
Average Interest Rate................. 8.2% 8.2% 8.2% 8.2% 8.2%
Fixed Rate (US$)........................ 122 122 122 122 122 2,090 2,700 3,188
Average Interest Rate................. 9.1% 9.1% 9.1% 9.1% 9.1% 9.1%
Derivative Financial Instruments:
GBP (pound sterling) Functional Currency
Currency Swap (Receive ESP/Pay US$)
Contract Amount....................... 458 458 (123)
Average Exchange Rate................. 0.0088
</TABLE>
The Group will normally enter into currency swaps to manage its exposure to
adverse movements in exchange rates on its foreign-denominated debt.
Neither the currency swaps nor the related foreign currency denominated
debt instruments have been included in the above tables when such swaps
effectively eliminate the foreign currency exposure in the cash flows of the
related foreign currency denominated debt instrument. As a result the total
nominal value and fair value of the above currency swaps will vary slightly from
the derivative instruments disclosures in the audited financial statements.
PetroFina also enters into foreign exchange forward contracts to manage its
exposure to fluctuations in foreign currency denominated receivables and
payables. Most of these contracts mature within three months. The Company is
obligated in its foreign exchange forward contracts outstanding at December 31,
1997 to purchase Belgian francs and dollars while selling other European
currencies, principally the German mark, French franc, Norwegian krone, and
British pound.
Management believes that these financial instruments do not subject
PetroFina to material risk due to foreign exchange movements because gains or
losses on these contracts will offset gains or losses on the assets, liabilities
and transactions being hedged. See Note 14 to "Item 18. Financial Statements."
COMMODITY PRICE SENSITIVITY
PetroFina also enters into crude oil and refined products futures and
forward contracts to minimize short term price risks related to the supply and
sale of these products, respectively. Natural gas futures are also used
53
<PAGE> 56
to hedge Upstream's United States equity production. At December 31, 1997, the
fair value of these commodity derivative instruments was BEF 12 million.
The value of these contracts is sensitive to changes in commodity prices.
If the price of the underlying commodities changes, it would have the opposite
effect on the fair value of the Group's commodity derivative instruments. Based
on an undiscounted cash flow approach, decreasing the forward rates of these
commodities by 10% would increase the fair value of these instruments by BEF 11
million, while increasing the forward rates by 10% would decrease the fair value
of these instruments by BEF 9 million. Given that there is no economic basis for
predicting for the magnitude of the change that will occur, the Company has
assumed a 10% positive and negative change.
The level of derivative commodity instruments is immaterial to the Group's
actual level of transactions. Therefore the changes in fair values noted above
would not have a material effect on the Group's results of operations or
financial position.
ITEM 10. DIRECTORS AND OFFICERS OF REGISTRANT
BOARD OF DIRECTORS
Set forth below for each director of the Company as of June 15, 1998, are
his name, position with the Company, the date as of which he initially commenced
serving as a director, the date his current term as a director expires and his
citizenship. All directors listed below are citizens of Belgium, except for Mr.
Vieira (Portugal); Messrs. Calvet, Dejouany and Mestrallet (France); and Messrs.
Desmarais, Sr., Desmarais, Jr. and Mulroney (Canada). Mr. de Rudder and Mr.
Samyn are citizens of both Belgium and France, and Mr. Beffa is a citizen of
both France and Switzerland.
<TABLE>
<CAPTION>
DIRECTOR TERM
NAME POSITION SINCE EXPIRES
---- -------- -------- -------
<S> <C> <C> <C>
Albert Frere............................... Chairman 1986 2001
Francois Cornelis.......................... Vice Chairman, Chief Executive 1986 2001
Officer & Managing Director
Etienne Davignon........................... Vice Chairman 1990 2002
Axel de Broqueville........................ Executive Director, Chemicals 1989 2001
Michel-Marc Delcommune..................... Executive Director, Corporate 1992 2001
Finance
Henrique Bandeira Vieira................... Executive Director, Marketing 1990 2002
Jean-Louis Beffa........................... Director 1988 2000
Yves Boel.................................. Director 1986 2001
Jacques Calvet............................. Director 1990 2001
Guy Dejouany............................... Director 1990 2002
Paul Desmarais, Sr. ....................... Director 1988 2000
Paul Desmarais, Jr. ....................... Director 1992 2001
Paul Janssen............................... Director 1987 1999
Jean-Pierre de Launoit..................... Director 1987 1999
Gerard Mestrallet.......................... Director 1994 2000
Brian Mulroney............................. Director 1994 2000
Thierry de Rudder.......................... Director 1990 2003
Gilles Samyn............................... Director 1990 2002
Luc Wauters................................ Director 1984 2002
</TABLE>
54
<PAGE> 57
Mr. Desmarais, Sr. and Mr. Desmarais, Jr. are father and son. Mr. Vieira
and Mr. Delcommune are brothers-in-law.
Baron Albert Frere is Chairman and Managing Director of Groupe Bruxelles
Lambert S.A. He is also Chairman of the Boards of Directors of Electrafina S.A.,
Erbe S.A., Fibelpar S.A. and Frere-Bourgeois S.A.; Vice President of COBEPA S.A.
and Royale Belge S.A.; Vice-Chairman and Managing Director of Pargesa Holding
S.A.; and a member of the International Committee of Compagnie Financiere de
Paribas S.A. He is also a director of Compagnie Nationale a Portefeuille S.A.,
Parfinance, LVMH, Havas and TF1. He is a member of the Supervisory Board of Suez
Lyonnaise des Eaux S.A. and an honorary member of the Council of Regents of the
Banque Nationale de Belgique. He was elected a director of the Company in 1986
and Chairman in 1990.
Mr. Francois Cornelis was elected a director in 1986, Managing Director and
Chief Executive Officer of Parent in 1990 and Vice-Chairman in 1991. He
graduated from the University of Louvain with a degree in mechanical engineering
in 1973 and joined PetroFina in the same year. He has held a number of positions
in various areas within the Group, including in the United Kingdom, the United
States and Belgium. In March 1984 he became Assistant General Manager attached
to the Chairman. He serves as Chairman to several Group subsidiaries. He is a
member of the European Advisory Board of the NYSE and a member of the European
Round Table of Industrialists. He has been Chairman of Europia since 1995.
Viscount Etienne Davignon is the Executive Chairman of Societe Generale de
Belgique S.A. He serves as Chairman of Compagnie Maritime Belge S.A., Sibeka
S.A. and Union Miniere S.A., and as a Vice-Chairman of Fortis AG. He is a
director of various companies, including BASF A.G., Generale de Banque, Sofina
S.A., Solvay S.A., Suez Lyonnaise des Eaux and Tractebel S.A. He has been active
in public affairs, in particular in the Belgian Ministry of Foreign Affairs, as
the first president of the International Energy Agency and as vice-president of
the European Commission. He was elected a director and Vice-Chairman of the
Company in 1990.
Mr. Axel de Broqueville graduated from the University of Louvain with a
degree in electronic engineering in 1966 and also holds an M.S. in Aeronautics
from Imperial College, London. He joined PetroFina in 1970 and held a number of
positions in Belgium and the United States before returning to PetroFina's
headquarters in Brussels. In 1986 he became Senior Vice-President, Chemicals and
was elected an Executive Director of the Company in 1989.
Mr. Michel-Marc Delcommune graduated from the University of Liege with a
degree in chemical engineering in 1971 and holds an M.B.A. from Cornell
University. He is a member of the International Advisory Board of Cornell
University and Chairman of the Financial Executives Council of the Conference
Board of Europe. He joined PetroFina in 1972. His occupations were mainly in
Data Processing and in Exploration and Production Departments in Belgium and
abroad. In 1986, he was appointed Vice-President of Corporate Finance and
Insurance and Senior Vice-President in 1990. In 1992, he was elected Executive
Director of the Company.
Mr. Henrique Bandeira Vieira graduated as a mining engineer from the
University of Lisbon in 1958, and holds an M.S. in Petroleum Engineering from
Stanford University and an M.B.A. from Boston University. He joined PetroFina in
1959 and has held several positions in the United States, Angola, Belgium and
the U.K. In 1985 he became Senior Vice President, Exploration and Production and
he was elected an Executive Director of the Company in 1990. In 1997 he was
appointed Executive Director, Marketing.
Mr. Jean-Louis Beffa is the Chairman and Chief Executive Officer of
Compagnie de Saint-Gobain and Vice-Chairman of Vivendi S.A. He is also a member
of the Boards of Directors of Banque Nationale de Paris and of the Supervisory
Board of AXA. He was elected a director of the Company in 1988.
Mr. Yves Boel is the Chairman of the Board of Directors and Chairman of the
Executive Committee of Sofina S.A. and Solvay S.A. He is also Vice-Chairman of
Tractebel S.A. and a director of GIB. He was elected a director of the Company
in 1986. He served as Chairman of SIDRO from 1968 until 1996.
55
<PAGE> 58
Mr. Jacques Calvet is a director of Vivendi S.A., Societe Generale S.A.
(France), Automobiles Peugeot and Automobiles Citroen. He is a member of the
Supervisory Board of AXA-UAP and a consulting advisor to the Banque de France.
He has been active in public affairs, in particular at the French Ministry of
Economy and Finance, and has been the President of the Board of Management of
Peugeot S.A. He was elected a director of the Company in 1990.
Mr. Guy Dejouany is Honorary President of Vivendi S.A. and of Compagnie des
Eaux et de l'Ozone. He is a member of the Board of Directors of Vivendi S.A.,
Compagnie de Saint Gobain, AlcatelAlsthom, Canal+, Havas, Electrafina S.A. and
Societe Generale S.A. He is also a member of the Supervisory Board of AXA-UAP.
He was elected a director of the Company in 1990.
Mr. Paul Desmarais, Sr. is the Chairman of the Executive Committee and a
Director of Power Corporation of Canada. Mr. Desmarais also serves as Chairman
of the International Advisory Council to Power Corporation of Canada. He is
Chairman of the Board and Managing Director of Pargesa Holding S.A.
(Switzerland), a director and member of the Executive Committee of Groupe
Bruxelles Lambert S.A., a director of Parfinance and director of a large number
of other companies. He is also a member of the International Advisory Committee
of Chase Manhattan Bank, N.A., Barrick Gold Corporation, China International
Trust and Investment Corporation (CITIC) and of the Supervisory Board of AXA-UAP
and of Compagnie Financiere de Paribas. He was elected a director of the Company
in 1988.
Mr. Paul Desmarais, Jr. is the Chairman of the Board and Co-Chief Executive
Officer of Power Corporation of Canada. He is also Chairman of the Board of
Power Financial Corporation, Chairman and Chief Executive Officer of Parfinance
(France) and a director of a large number of other companies, including Pargesa
Holding S.A., Groupe Bruxelles Lambert S.A., Tractebel S.A. and Royale Belge
S.A. He is a member of the Board of INSEAD. He was elected a director of the
Company in 1992.
Baron Paul Janssen is the Chairman of Janssen Research Foundation
Worldwide. He is the author of a number of scientific publications and the owner
of a large number of patents. He was elected a director of the Company in 1987.
Count Jean-Pierre de Launoit is Chairman of Royale Belge S.A., Audiofina,
RTL-TVi and Euro-Clinvest. He is a director of GIB Group and of Groupe Bruxelles
Lambert France. He was elected a director of the Company in 1987.
Mr. Gerard Mestrallet is the Chairman of the Managing Board of Suez
Lyonnaise des Eaux. He is also Vice-Chairman of the Board and chairman of the
Executive Committee of Societe Generale de Belgique and Chairman of the Board of
Tractebel. He is also a director of Compagnie de Saint-Gobain, and a member of
the Supervisory Board of AXA. He was elected a director of the Company in 1994.
The Right Honorable Brian Mulroney was the Prime Minister of Canada from
1984 until 1993. In 1993, Mr. Mulroney became a Senior Partner in Ogilvy
Renault. He is Chairman of the International Advisory Board of Barrick Gold
Corporation and a director of other large companies. He was elected a director
of the Company in 1994.
Mr. Thierry de Rudder is Managing Director of Groupe Bruxelles Lambert S.A.
and Electrafina. He is also a member of the Board of Directors of Audiofina,
Bernheim-Comofi, Compagnie Nationale a Portefeuille S.A., Monument Oil and Gas
p1c., Royale Belge, Tractebel and Societe Generale de Belgique S.A. He was
elected a director of the Company in 1990.
Mr. Gilles Samyn is Managing Director of Frere-Bourgeois, Compagnie
Nationale a Portefeuille S.A., Erbe S.A. and Fibelpar S.A. He is a member of the
Executive Committee of Pargesa and Groupe Bruxelles Lambert, and a Director of
other companies including IMETAL and CLT-UFA. He is the Chairman of the Board of
various companies including Transcor. He was elected a director of the Company
in 1990.
Baron Luc Wauters is Honorary Chairman of Kredietbank N.V. (KBC-Bank) and
of Almanij N.V. He is founding Chairman of Almanij-Kredietbank Group (Almanij
Group). He is also a director of Bayer Antwerp. He was elected a director of the
Company in 1984.
56
<PAGE> 59
In accordance with Belgian law governing a societe anonyme/naamloze
vennootschap, the Company's affairs are managed by its Board of Directors (the
"Board"). Responsibility for management of the Company's daily affairs has been
conferred by the Board to its Vice-Chairman & Chief Executive Officer, its
Executive Directors, General Managers and Secretary General, acting and making
decisions in pairs.
Under Parent's Articles, the Board consists of not less than 7, nor more
than 20, members. The Board is presently composed of 19 members. Shareholders of
the Company entitled to vote at ordinary general shareholders' meetings elect
the directors.
In May 1990, the Board adopted a resolution regarding the composition of
the Board. Pursuant to the resolution, of the then twenty directors, six were to
be officers of the Company, four were to be independent persons, six were to be
proposed by Groupe Bruxelles Lambert S.A. ("GBL"), three were to be proposed by
Societe Generale de Belgique S.A. ("SGB"), and one was to be proposed by
Compagnie Nationale Portefeuille S.A. ("CNP") (which is presently affiliated
with GBL). Of the nineteen directors currently on the Board, six are associated
with GBL (Messrs. Frere, Dejouany, de Launoit, de Rudder, Desmarais, Sr., and
Desmarais, Jr.), three are associated with SGB (Messrs. Davignon, Boel and
Mestrallet), one is associated with CNP (Mr. Samyn), four are executive officers
of the Company (Messrs. Cornelis, de Broqueville, Delcommune and Vieira), and
five are regarded by GBL and SGB as not associated with GBL, SGB or CNP (Messrs.
Beffa, Calvet, Janssen, Mulroney and Wauters). See also "Item 4. Control of
Registrant."
The Company's Articles currently provide that each director elected by the
shareholders may serve for a term not to exceed six years. Directors need not be
Belgian nationals, and there is no limitation on the number of terms that a
director may serve. Under Belgian law, the Board has full executive authority to
manage the affairs of the Company in the Company's interest. Pursuant to the
Company's Articles, the Board has the power to perform all acts necessary or
useful to achieve the corporate purpose, except for those reserved by law to the
general shareholders' meeting. In addition to reviewing and monitoring the
Company's business, the powers generally held by the Board include the oversight
of the Company's year-end and semi-annual accounts, the presentation of the
year-end accounts to the shareholders and the convening of general shareholders'
meetings. Under Belgian law, directors may be liable for damages to the Company
in case of improper performance of their duties. They may be liable for damages
to the Company and to third parties for infringement of the Articles or the
Belgian company law or tortious conduct. Under certain circumstances, directors
may also be criminally liable.
There are three committees of the Board: (1) the Compensation Committee,
which recommends director compensation; (2) the Finance and Audit Committee,
which oversees PetroFina's accounting standards, election of auditors and
financial reporting; and (3) the Core Committee, which serves in an advisory
capacity to the Group's management on important corporate matters. No executive
officers of the Company serve on the Compensation Committee.
57
<PAGE> 60
EXECUTIVE OFFICERS
The Company's current executive officers and the first date as of which he
served as an executive officer are set forth below.
<TABLE>
<CAPTION>
EXECUTIVE
NAME POSITION OFFICER SINCE
---- -------- -------------
<S> <C> <C>
Francois Cornelis..................... Chief Executive Officer and Managing Director 1984
Axel de Broqueville................... Executive Director, Chemicals 1985
Michel-Marc Delcommune................ Executive Director, Corporate Finance 1990
Henrique Bandeira Vieira.............. Executive Director, Marketing 1985
William Bracke........................ General Manager, Research 1990
Wayne Brenckle........................ General Manager, Manufacturing and Logistics 1990
Jean Castelein........................ General Manager, Health, Safety, Environment 1995
& Quality
Jacques de Naurois.................... General Manager, Supply 1984
Jose G. Rebelo........................ General Manager, Exploration -- Production 1992
Francois Vincke....................... Secretary General, Legal 1988
Malcolm Webb.......................... General Manager, Human Resources 1995
</TABLE>
ITEM 11. COMPENSATION OF DIRECTORS AND OFFICERS
For the year ended December 31, 1997, the aggregate amount paid by the
Company for compensation of its directors and executive officers as a group (27
persons) for services in all capacities was approximately BEF 193 million.
ITEM 12. OPTIONS TO PURCHASE SECURITIES FROM REGISTRANT OR SUBSIDIARIES
Under Belgian law, shareholders of the Company have preferential
subscription rights, in proportion to the number of PetroFina Shares held by
them, in respect of issues of new PetroFina Shares for cash by the Company. This
preferential subscription right, however, may be either limited or removed by a
resolution passed at a general meeting of shareholders. At the general meeting
of shareholders on May 10, 1996, the Board was authorized, for a period of 5
years (expiring on June 22, 2001) to limit or remove the preferential
subscription rights in connection with an increase in the Company's subscribed
capital of up to BEF 15 billion (8,055,054 PetroFina Shares). Such permission
may be renewed, through a vote at a general meeting of shareholders. The Board
has removed the preferential subscription rights with respect to the issuance of
the PetroFina Warrants and the issuance of PetroFina ADSs upon exercise of the
PetroFina Warrants.
On May 29, 1997, the Company decided to issue warrants to purchase 150,000
PetroFina Shares to its employees, including its executive officers. The
warrants will have an exercise price of BEF 12,500 per PetroFina Share and will
expire on June 30, 2000. No warrants will be issued to any director who is not
also an executive officer of the Company.
Other than the 150,000 warrants discussed above and the PetroFina Warrants
to be issued in the Merger (see "Item 1. Description of Business -- Other
Matters Pending Transaction"), there are no outstanding options or warrants to
acquire PetroFina Shares.
ITEM 13. INTEREST OF MANAGEMENT IN CERTAIN TRANSACTIONS
Neither any executive officer or director of the Company, nor any associate
of any such person is indebted to the Company or any of its subsidiaries.
58
<PAGE> 61
PART II
ITEM 14. DESCRIPTION OF SECURITIES TO BE REGISTERED
Not applicable.
PART III
ITEM 15. DEFAULTS UPON SENIOR SECURITIES
Not applicable.
ITEM 16. CHANGES IN SECURITIES AND CHANGES IN SECURITY FOR REGISTERED SECURITIES
Not applicable.
PART IV
ITEM 17. FINANCIAL STATEMENTS
Not applicable.
ITEM 18. FINANCIAL STATEMENTS
See pages F-1 through F-42, incorporated herein by reference.
ITEM 19. FINANCIAL STATEMENTS AND EXHIBITS
(a) FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
PAGE NO.
--------
<S> <C>
Reports of Independent Auditors............................. F-1
Consolidated Balance Sheets at December 1, 1997, 1996 and
1995...................................................... F-10
Consolidated Statements of Income for the Years Ended
December 31, 1997, 1996
and 1995.................................................. F-11
Consolidated Statements of Cash Flows for the Years Ended
December 31, 1997, 1996 and 1995.......................... F-12
Consolidated Statements of Changes in Shareholders' Equity
for the Years Ended December 31, 1997, 1996 and 1995...... F-13
Notes to Consolidated Financial Statements.................. F-14
Financial Statement Schedule................................ F-43
</TABLE>
(b) EXHIBITS
The following documents are filed as part of this Registration Statement:
1. Deposit Agreement (incorporated by reference to Exhibit 1 to the
Company's Amendment No. 2 to Registration Statement on Form F-6, File No.
33-34102, filed with Commission on April 16, 1998).
59
<PAGE> 62
SIGNATURES
Pursuant to the requirements of Section 12 the Securities Exchange Act of
1934 as amended, the registrant certifies that it meets all of the requirements
for filing on Form 20-F and has duly caused this annual report to be signed on
its behalf by the undersigned, thereunder duly authorized.
PetroFina
By: /s/ MICHEL-MARC DELCOMMUNE
------------------------------------
Name: Michel-Marc Delcommune
Title: Executive Director
By: /s/ FRANCOIS VINCKE
------------------------------------
Name: Francois Vincke
Title: Secretary General, Legal
Date June 26, 1998
------------------------------
60
<PAGE> 63
[DELOITTE & TOUCHE LOGO]
INDEPENDENT AUDITORS' REPORT
To the Directors and Shareholders of
PetroFina S.A.
We have audited the accompanying consolidated balance sheets of PetroFina
S.A. and subsidiaries as of December 31, 1997, 1996 and 1995, and the related
consolidated statements of income, shareholders' equity and cash flows for the
years then ended. These consolidated financial statements are the responsibility
of the Company's management. Our responsibility is to express an opinion on
these consolidated financial statements based on our audits. We did not audit
the financial statements of certain subsidiaries which statements reflect total
assets constituting 45.0%, 51.5% and 48.2%, respectively, of consolidated total
assets at December 31, 1997, 1996 and 1995, and total revenues constituting
33.9%, 46.6% and 45.9%, respectively, of consolidated total revenues for the
years then ended. Those financial statements were audited by other auditors
whose reports have been furnished to us, and our opinion, insofar as it relates
to the amounts included for such subsidiaries, before conversion to generally
accepted accounting principles in the United States, is based solely on the
reports of such other auditors.
We conducted our audits in accordance with generally accepted auditing
standards in the United States. 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 (which include the conversion
to generally accepted accounting principles in the United States) and the
reports of the other auditors provide a reasonable basis for our opinion.
In our opinion, based on our audits and the reports of the other auditors,
such consolidated financial statements present fairly, in all material respects,
the financial position of PetroFina S.A. at December 31, 1997, 1996 and 1995,
and the results of their operations and their cash flows for the years then
ended in conformity with generally accepted accounting principles in the United
States.
/s/ Michael C. Vaes
Michael C. Vaes
Statutory Auditor
Deloitte & Touche Reviseurs d'Entreprises scc
Brussels, Belgium
March 26, 1998
F-1
<PAGE> 64
[KPMG LOGO]
INDEPENDENT AUDITORS REPORT
To the Directors of PetroFina S.A.
We have audited the balance sheets of Fina Europe N.V. (a 99,9 percent
subsidiary of PetroFina S.A.) as of 31 December 1997, 1996 and 1995 and related
statements of income for each of the three years in the period ended December
31, 1997 (not presented separately herein). These financial statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States. Those standards require that we plan and perform
the audit to obtain reasonable assurance about whether these 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 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 financial position of Fina Europe N.V. at December
31, 1997, 1996 and 1995, and the results of its operations for each of the three
years in the period ended December 31, 1997 in conformity with generally
accepted accounting principles in Belgium.
Antwerp, Belgium
March 20, 1998
Klynveld Peat Marwick Goerdeler Reviseurs d'Entreprises
Represented by
L. Ruysen
F-2
<PAGE> 65
[KPMG LOGO]
INDEPENDENT AUDITORS REPORT
To the Directors of PetroFina S.A.
We have audited the balance sheets of Fina Raffinaderij Antwerpen N.V. (a
99,9 percent subsidiary of PetroFina S.A.) as of 31 December 1997, 1996 and 1995
and related statements of income for each of the three years in the period ended
December 31, 1997 (not presented separately herein). These financial statements
are the responsibility of the Company's management. Our responsibility is to
express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States. Those standards require that we plan and perform
the audit to obtain reasonable assurance about whether these 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 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 financial position of Fina Raffinaderij Antwerpen
N.V. at December 31, 1997, 1996 and 1995, and the results of its operations for
each of the three years in the period ended December 31, 1997 in conformity with
generally accepted accounting principles in Belgium.
Antwerp, Belgium
March 20, 1998
Klynveld Peat Marwick Goerdeler Reviseurs d'Entreprises
Represented by
/s/ L. Ruysen
L. Ruysen
F-3
<PAGE> 66
[KPMG LOGO]
INDEPENDENT AUDITORS' REPORT
TO THE DIRECTORS OF PETROFINA S.A.
We have audited the balance sheets of Sigma Coatings B.V. (a wholly-owned
subsidiary of PetroFina S.A.) as of December 31, 1997, 1996 and 1995 and the
related statements of income for each of three years in the period ended
December 31, 1997 (not presently separately herein). These financial statements
are the responsibility of the company's management. Our responsibility is to
express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States. 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 financial position of Sigma Coatings B.V. as of
December 31, 1997, 1996 and 1995, and the results of its operations for each of
the three years in the period ended December 31, 1997, in conformity with
generally accepted accounting principles in the Netherlands.
The Hague, the Netherlands, March 20, 1998
/s/ KPMG Accountants NV
F-4
<PAGE> 67
[KPMG LOGO]
INDEPENDENT AUDITORS' REPORT
The Board of Directors
Petrofina S.A.:
We have audited the accompanying consolidated balance sheets of Petrofina
Delaware, Incorporated and subsidiaries (a wholly-owned subsidiary of PetroFina
S.A.) as of December 31, 1997, 1996 and 1995, and the related consolidated
statements of earnings, stockholder's equity and cash flows for each of the
years in the three-year period ended December 31, 1997 (not presented separately
herein). These consolidated financial statements are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
consolidated 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 consolidated financial statements referred to above
present fairly, in all material respects, the financial position of Petrofina
Delaware, Incorporated and subsidiaries as of December 31, 1997, 1996 and 1995,
and the results of their operations and their cash flows for each of the years
in the three-year period ended December 31, 1997 in conformity with generally
accepted accounting principles.
/s/ KPMG PEAT MARWICK LLP
Dallas, Texas
January 26, 1998, except as to the
fourth paragraph of note 1(a)
which is as of February 17, 1998
F-5
<PAGE> 68
[KPMG LOGO]
INDEPENDENT AUDITORS' REPORT
To the Directors of
PetroFina S.A.
We have audited the balance sheets of Brittany Insurance Company Ltd. (a
wholly-owned subsidiary of PetroFina S.A.) as of December 31, 1997 and 1996 and
related statements of income and cash flows for each of the two years in the
period ended December 31, 1997 (not presented separately herein). These
financial statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States. Those standards require that we plan and perform
an audit to obtain reasonable assurance about whether these 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 financial position of Brittany Insurance Company
Ltd. at December 31, 1997 and 1996 and the results of its operations and cash
flows for each of the two years in the period ended December 31, 1997 in
conformity with generally accepted accounting principles in the United States.
/s/ KPMG PEAT MARWICK
Chartered Accountants
Hamilton, Bermuda
February 10, 1998
F-6
<PAGE> 69
[KPMG LOGO]
INDEPENDENT AUDITORS' REPORT
To the Board of Directors of
PetroFina S.A.
We have audited the balance sheet of Brittany Insurance Company Ltd. as at
December 31, 1995 and the statements of operations and retained earnings and
changes in financial position for the year then ended. These financial
statements are the responsibility of the company's management. Our
responsibility is to express an opinion on these financial statements based on
our audit.
We conducted our audit in accordance with generally accepted auditing
standards in Bermuda and Canada that are substantially equivalent to auditing
standards generally accepted in the United States. Those standards require that
we plan and perform an audit to obtain reasonable assurance 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.
In our opinion, these financial statements present fairly, in all material
respects, the financial position of the company as at December 31, 1995 and the
results of its operations and the changes in its financial position for the year
then ended in accordance with generally accepted accounting principles in
Bermuda and Canada.
/s/ KPMG PEAT MARWICK
Chartered Accountants
Hamilton, Bermuda
February 28, 1997
F-7
<PAGE> 70
[KPMG LOGO]
REPORT OF INDEPENDENT AUDITORS
To the Directors of Fina Plc:
We have audited the balance sheet of Fina plc (a wholly-owned subsidiary of
PetroFina SA) as of December 31, 1996 and 1995 and the related statements of
profit and loss and cash flows for each of the years in the two year period
ended December 31, 1996. These financial statements are the responsibility of
the Company's management. Our responsibility is to express an opinion on these
financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United Kingdom that are substantially equivalent to auditing
standards generally accepted in the United States. 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.
The basis of valuation of stock in the accompanying balance sheets, which
has been applied consistently since 1971, does not comply with Statement of
Standard Accounting Practice Number 9 (Revised) in that cost is ascertained, in
part, on a last in first out basis. Were stock to have been valued on a first
in first out basis, the value of stock in the balance sheet would have
increased by pound sterling 4,880,000 and pound sterling 3,092,000 as of
December 31, 1996 and 1995 respectively, and the profit before taxation for the
years ended December 31, 1996 and 1995 would have increased by pound sterling
1,788,000 and pound sterling 2,595,000 respectively.
In our opinion, except for the effects of valuation of stock as discussed
in the preceding paragraph, the financial statements referred to above present
fairly, in all material respects, the financial position of Fina plc as of
December 31, 1996 and 1995, and the results of its operations and its cash flows
for each of the years in the two-year period ended December 31, 1996, in
conformity with generally accepted accounting principles in the United Kingdom.
/s/ KPMG AUDIT PLC
KPMG Audit Plc
Chartered Accountants
Registered Auditor
London, England
April 14, 1997
F-8
<PAGE> 71
[KPMG LOGO]
REPORT OF INDEPENDENT AUDITORS
To the Directors of Fina Exploration Norway SCA:
We have audited the balance sheet of The Branch of Fina Exploration Norway
SCA (a wholly-owned subsidiary of Petrofina SA) as of December 31, 1996 and 1995
and the related statements of profit and loss and cash flows for each of the
years in the two-period period ended December 31, 1996. These financial
statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with auditing standards generally
accepted in Norway that are substantially equivalent to auditing standards
generally accepted in the United States. 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 financial position of The Branch of Fina
Exploration Norway SCA as of December 31, 1996 and 1995, and the results of its
operations and its cash flows for each of the years in the two-year period ended
December 31, 1996, in conformity with generally accepted accounting principles
in Norway.
Sandvika, January 27, 1997
KPMG as
/s/ Jorgen Lorentzen-Styr
Jorgen Lorentzen-Styr
F-9
<PAGE> 72
PETROFINA
CONSOLIDATED FINANCIAL STATEMENTS
CONSOLIDATED BALANCE SHEETS
(in BEF millions)
<TABLE>
<CAPTION>
FOR THE YEARS ENDED DECEMBER 31,
---------------------------------
1997 1996 1995
--------- --------- ---------
<S> <C> <C> <C>
FIXED ASSETS
Intangible Assets........................................... 2,266 1,997 1,980
Tangible Assets............................................. 235,155 211,167 195,155
Financial Assets............................................ 6,879 6,597 6,587
Other Assets................................................ 11,794 11,272 9,450
------- ------- -------
256,094 231,033 213,172
CURRENT ASSETS
Stocks...................................................... 51,559 48,175 45,033
Trade Debtors............................................... 73,540 69,068 58,678
Other Debtors............................................... 12,127 10,904 10,323
Marketable Securities....................................... 6,640 4,885 3,844
Cash and Cash Equivalents................................... 3,658 2,723 2,842
------- ------- -------
147,524 135,755 120,720
Total Assets........................................... 403,618 366,788 333,892
======= ======= =======
CREDITORS AMOUNTS FALLING DUE WITHIN ONE YEAR
Finance Debt................................................ 30,186 35,643 34,605
Income Tax Payable.......................................... 8,915 10,130 6,346
Trade Creditors............................................. 52,678 46,002 40,902
Other Creditors............................................. 36,987 37,048 35,362
------- ------- -------
128,766 128,823 117,215
CREDITORS AMOUNTS FALLING DUE AFTER ONE YEAR
Finance Debt................................................ 59,976 49,326 44,732
PROVISIONS FOR LIABILITIES AND CHARGES
Deferred Taxation........................................... 26,560 22,809 19,645
Other Provisions............................................ 25,556 25,056 24,216
------- ------- -------
112,092 97,191 88,593
Minority Shareholders' Interests............................ 6,845 5,763 4,986
SHAREHOLDERS' EQUITY........................................ 155,915 135,011 123,098
Subscribed Capital.......................................... 43,605 43,293 43,293
Share Premium............................................... 26,096 24,314 24,310
Retained Earnings........................................... 107,738 94,979 87,216
Cumulative Foreign Currency Translation Adjustment.......... (21,524) (27,575) (31,721)
------- ------- -------
155,915 135,011 123,098
Total Liabilities and Shareholders' Equity............. 403,618 366,788 333,892
======= ======= =======
</TABLE>
See accompanying notes to consolidated financial statements.
F-10
<PAGE> 73
PETROFINA
CONSOLIDATED STATEMENTS OF INCOME
(in BEF millions, except number of shares and per share data)
<TABLE>
<CAPTION>
FOR THE YEARS ENDED DECEMBER 31,
------------------------------------
1997 1996 1995
---------- ---------- ----------
<S> <C> <C> <C>
Operating Revenue including Duties and Excise Taxes...... 727,031 622,145 558,724
Earnings from Investments, Equity Interests.............. 1,386 1,466 1,345
---------- ---------- ----------
Total Revenue............................................ 728,417 623,611 560,069
Cost of Products Sold.................................... (315,785) (259,484) (220,216)
Duties and Excise Taxes.................................. (234,070) (206,955) (195,414)
Direct Operating Expenses................................ (61,149) (54,514) (52,287)
Sales, General and Administrative Costs.................. (28,720) (27,662) (26,241)
Depreciation, Depletion and Amortization................. (28,703) (23,775) (22,533)
Exploration Costs........................................ (4,354) (3,030) (4,186)
Other Operating Costs.................................... (7,875) (7,661) (7,501)
Early Retirement Costs................................... (928) (1,142) (903)
---------- ---------- ----------
OPERATING INCOME......................................... 46,833 39,388 30,788
Interest Expense......................................... (4,691) (5,585) (6,079)
Other Financial Income, Net.............................. 95 519 908
---------- ---------- ----------
Income before Taxes and Minority Interests............... 42,237 34,322 25,617
Current Income Tax....................................... (16,839) (16,296) (12,150)
Deferred Income Tax...................................... (2,692) (1,382) (942)
Minority Interest........................................ (646) (696) (699)
---------- ---------- ----------
NET INCOME............................................... 22,060 15,948 11,826
Earnings per Share....................................... 945 686 509
Weighted average number of Shares used to calculate
Earnings per Share (basic and dilutive)................ 23,350,612 23,252,764 23,252,414
</TABLE>
See accompanying notes to consolidated financial statements.
F-11
<PAGE> 74
PETROFINA
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in BEF millions)
<TABLE>
<CAPTION>
FOR THE YEARS ENDED DECEMBER 31,
---------------------------------
1997 1996 1995
--------- --------- ---------
<S> <C> <C> <C>
CASH-FLOW FROM OPERATING ACTIVITIES
Net Income.................................................. 22,060 15,948 11,826
Minority Interest........................................... 646 696 699
Adjustments to Reconcile Net Earnings to Net Cash Provided
by Operating Activities:
Depreciation, Depletion, and Amortization (including
exploration costs)................................... 32,333 26,141 25,912
Provisions for Liabilities and Charges................. (1,163) (317) 502
Provisions for Losses on Accounts Receivable and
Inventories.......................................... 574 115 (221)
Deferred Income Taxes.................................. 2,692 1,382 942
------- ------- -------
CASH-FLOW (*)............................................... 57,142 43,965 39,660
Equity in Net Income of Affiliated Companies Net of
Dividend Received.................................... (223) (315) 300
Gain on Sales of Assets................................ (467) (1,334) (186)
Changes in Working Capital:
-- Accounts Receivable............................ (526) (6,701) 15
-- Inventories.................................... (1,020) (682) (3,148)
-- Trade Payables................................. 3,149 2,845 1,056
-- Other Current Liabilities...................... (2,229) 3,167 2,128
-- Income Tax Payable............................. (1,582) (860) 35
-- Other.......................................... (318) (3,266) (2,012)
------- ------- -------
Net Cash Provided by Operating Activities......... 53,926 36,819 37,848
CASH FLOWS FROM INVESTING ACTIVITIES
Capital Expenditure Including Exploration expenses.......... (43,246) (32,203) (26,695)
Proceeds from Sales of Assets............................... 1,571 4,122 1,975
Investments in Affiliates................................... (414) (939) (3,157)
------- ------- -------
Net Cash Used in Investing Activities............. (42,089) (29,020) (27,877)
CASH FLOWS FROM FINANCING ACTIVITIES
Additions to Long Term Debt................................. 17,533 13,877 2,424
Payments of Long Term Debt.................................. (9,423) (16,825) (3,725)
Net Change in Short Term Notes Payable...................... (11,392) 3,455 (287)
Warrant Exercise Proceeds................................... 2,095 4 3
Minority Interest........................................... 7 12 16
Dividend Paid to the Minority Interest...................... (518) (353) (356)
Dividend Paid............................................... (9,301) (8,185) (7,441)
------- ------- -------
Net Cash Used in Financing Activities............. (10,999) (8,015) (9,366)
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS........ 838 (216) 605
Cash and Cash Equivalents at Beginning of Year.............. 2,723 2,842 2,274
Cash and Cash Equivalents at End of Year.................... 3,658 2,723 2,842
Effect of Exchange Rate Changes............................. 97 97 (37)
------- ------- -------
Net Increase (Decrease) in Cash and Cash Equivalents........ 838 (216) 605
Income Taxes Paid........................................... (18,297) (13,070) (12,016)
Interest Paid............................................... (6,876) (6,883) (6,620)
</TABLE>
- ---------------
(*) PetroFina defines "Cash Flow", for purposes of its Belgian financial
reporting, as consolidated net income adjusted for depreciation and other
current year provisions to net income.
F-12
<PAGE> 75
PETROFINA
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
(in BEF millions except number of shares and per share data)
<TABLE>
<CAPTION>
CUMULATIVE
ORDINARY SHARES ISSUED FOREIGN
---------------------- ADDITIONAL CURRENCY TOTAL
STATUTORY PAID-IN RETAINED TRANSLATION SHAREHOLDERS'
NUMBER CAPITAL CAPITAL EARNINGS ADJUSTMENT EQUITY
---------- --------- ---------- -------- ----------- -------------
<S> <C> <C> <C> <C> <C> <C>
Balance December 31, 1994......... 23,252,229 43,292 24,308 82,831 (26,933) 123,498
Warrants Exercised................ 222 1 2 3
Net Income 1995................... 11,826 11,826
Dividend Declared and Paid
(BEF 320 Per Share)............. (7,441) (7,441)
Foreign Currency Translation...... (4,788) (4,788)
---------- ------ ------ ------- ------- -------
Balance December 31, 1995......... 23,252,451 43,293 24,310 87,216 (31,721) 123,098
Warrants Exercised................ 412 4 4
Net Income 1996................... 15,948 15,948
Dividend Declared and Paid
(BEF 352 Per Share)............. (8,185) (8,185)
Foreign Currency Translation...... 4,146 4,146
---------- ------ ------ ------- ------- -------
Balance December 31, 1996......... 23,252,863 43,293 24,314 94,979 (27,575) 135,011
Warrants Exercised................ 167,569 312 1,782 2,094
Net Income 1997................... 22,060 22,060
Dividend Declared and Paid
(BEF 400 Per Share)............. (9,301) (9,301)
Foreign Currency Translation...... 6,051 6,051
---------- ------ ------ ------- ------- -------
Balance December 31, 1997......... 23,420,432 43,605 26,096 107,738 (21,524) 155,915
========== ====== ====== ======= ======= =======
</TABLE>
The statutory capital and additional paid-in capital of PetroFina S.A.
constitutes the nondistributable portion of Shareholders' Equity and is not
available for dividend purposes. Included in Shareholders' Equity for the Group
are retained earnings of certain subsidiary companies, under current debt
covenants or companies' acts, amounting to BEF 40.8 billion that are not
currently available for dividend distribution within the Group at December 31,
1997.
The Company has issued and outstanding 23,420,432 shares as of December 31,
1997 with aggregate subscribed capital of BEF 43,605,279,966 (BEF 1,862 per
share). By decision of the Company's shareholders, the Company's Board of
Directors is authorized to increase statutory capital by BEF 14.7 billion
(representing 7,888,285 shares).
The authorization is valid for a five-year period and available for renewal
at the end of the five-year term.
F-13
<PAGE> 76
PETROFINA
NOTES TO FINANCIAL STATEMENTS
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
The accompanying consolidated financial statements present the financial
position, results of operations and cash flows of PetroFina S.A. and its
consolidated subsidiaries (the "Group" or "PetroFina") and have been prepared in
accordance with United States generally accepted accounting principles (US
GAAP). The consolidated financial statements are presented in Belgian Franc
(BEF). All amounts presented are in BEF million unless otherwise indicated.
Following Belgian accounting laws, the Group is obliged to prepare its
financial statements in accordance with Belgian accounting principles. Following
article 8 of the Royal Decree dated 1st September 1986 concerning annual
financial statements and consolidated financial statements, the Belgian
Securities Exchange Commission (la Commission bancaire et financiere) authorized
PetroFina to depart from article 6 of the previous mentioned Royal Decree. This
departure allows PetroFina to prepare and publish the financial statements under
US GAAP. This authorisation is contingent upon the following conditions :
- PetroFina follows all US GAAP requirements
- PetroFina abides by all mandatory rules of the 7th European
Directive.
The decision by PetroFina to prepare and publish its financial statements
in accordance with US GAAP was based on the following :
- The registration of PetroFina securities with the New York Stock
Exchange obligates the Group to meet the reporting requirements of
the United States Securities and Exchange Commission. The Group is
required to prepare US GAAP financial statements or to prepare a
reconciliation to US GAAP.
- The Group's desire to publish comparable financial information
following the same format as other major worldwide energy companies.
In preparing the financial statements following US GAAP, the Group has
found no material contradiction with the mandatory rules of the 7th European
Directive.
USE OF ESTIMATES
The preparation of financial statements in conformity with US GAAP requires
management to make estimates and assumptions that affect the reported amounts of
assets and liabilities at the date of the financial statements and the reported
amounts of revenues and expenses during the reporting period. Actual results
could differ from those estimates.
BASIS OF CONSOLIDATION
Subsidiaries in which the Group's holdings exceed 50% are consolidated in
the financial statements, unless effective control is limited due to contractual
provisions or governmental restrictions. The Group consolidates certain jointly
controlled entities in accordance with the proportionate consolidation method.
Under U.S. GAAP these companies should be accounted for under the equity method
(see note 22). All material intercompany transactions are eliminated in
consolidation.
The equity method of accounting is used for investments in which the
investment provides the Group with the ability to exercise significant influence
over the operating and financial policies of the investee company. In the
absence of other evidence, such influence is presumed to exist for investments
in companies in which the Group's direct or indirect ownership is between 20%
and 50% of total voting rights. Under the equity method, the Group's share of
profits and losses of associated companies is included in the consolidated
income statement and the carrying value of the Group's investment is adjusted.
F-14
<PAGE> 77
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES -- (CONTINUED)
The cost method of accounting is used for investments in which the Group's
ownership is less than 20% or for investees where the Group is unable to
exercise significant influence.
A full list of consolidated companies and companies excluded from the scope
of consolidation is available from the Public Relations and Communication
Department of PetroFina S.A., rue de l'Industrie 52, B-1040 Brussels.
FOREIGN CURRENCY TRANSACTIONS
Foreign currency transactions are recorded at the exchange rate on the date
of origin. Monetary assets and liabilities denominated in a foreign currency are
revalued at each balance sheet date for the effect of exchange rate changes
between the date of origin and settlement date. The resulting gains and losses
on revaluation are recorded in the consolidated income statement as other
financial income or expense.
FOREIGN SUBSIDIARIES
The income statements of foreign subsidiaries are translated into BEF at
the average rate of exchange prevailing during the year. Balance sheets are
translated at the exchange rate at the balance sheet date. Differences arising
on the translation of financial statements of foreign subsidiaries are recorded
to shareholders' equity as cumulative foreign currency translation adjustments.
Exchange rate differences attributable to loans and forward exchange
agreements in foreign currencies that are designated as a hedge of the net
assets of a foreign subsidiary are recorded directly to shareholders' equity,
together with the corresponding translation difference on the hedged net assets.
DERIVATIVE FINANCIAL INSTRUMENTS
PetroFina manages risk arising from fluctuations in interest rates and
currency exchange rates by using derivative financial instruments, and risks
from fluctuations in the price of crude oil, refined products, and natural gas
by using derivative commodity instruments. PetroFina does not enter into
derivative instruments for speculative trading purposes.
PetroFina's derivative financial instruments currently include interest
rate swaps, currency swaps, and foreign exchange forward contracts. The interest
rate swaps are accounted for under the accrual basis of accounting. The foreign
exchange forward contracts and currency swaps are recorded at cost and adjusted
for changes in the spot exchange rates at the reporting date. With respect to
derivative commodity instruments, PetroFina currently enters into crude oil and
refined product futures and forwards and natural gas futures.
Interest rate swap agreements are used by PetroFina to manage its interest
costs and reduce interest rate risk by managing the overall mix of fixed and
floating rate debt. PetroFina is able to modify the interest characteristics of
its debt portfolio from a fixed to a floating rate basis or vice versa. Interest
differentials are recorded on an accrual basis as an adjustment to interest
expense and interest payable.
Currency swaps and foreign exchange forward contracts are used by PetroFina
to manage funding costs and its exposure to fluctuations in foreign currency
denominated receivables and payables. This activity is intended to protect
PetroFina cash flows from adverse short term fluctuations in foreign currencies.
Gains and losses attributable to these contracts resulting from changes in
exchange rates are accrued in other current receivables/liabilities and
recognized as an adjustment to other financial income and expense in the period
in which the change occurs.
When a hedged obligation is terminated without being replaced by another
qualifying hedged item, the designated interest rate or currency swap is
recorded at fair value.
F-15
<PAGE> 78
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES -- (CONTINUED)
Crude oil and refined products futures and forwards are used to minimize
price risks related to the supply and sale of these products, respectively. Any
realized or unrealized changes in fair value are accrued in other current
receivables/liabilities and recognized as a component of operating expenses in
the period in which the change occurs.
Natural gas futures are used to hedge designated equity production. Gains
and losses on these qualifying hedges are deferred and included in the
measurement of the related transaction, in the month of production.
Derivative instruments are either exchange-traded or with counterparties of
high credit quality. Therefore the risk of nonperformance by the counterparties
is considered to be negligible.
CASH AND CASH EQUIVALENTS
The Group considers all highly liquid investments with an original maturity
of three months or less to be cash equivalents.
MARKETABLE SECURITIES
The Group's investments in marketable securities are classified as
"trading" and are recorded at fair value. Changes in fair value, both unrealized
gains and unrealized losses, are recognized in each period's income statement.
STOCKS
Inventories are valued at the lower of cost or net realizable value. Crude
feedstocks, finished petroleum products and chemical products inventories are
valued according to the LIFO method (last in/first out). All other inventories
are valued at the lower of average cost (which approximates cost on a first
in/first out basis) or net realizable value. The costs of finished products
include raw material costs, direct costs and related production overhead costs
but exclude any interest charges. Net realizable value is defined as the
estimated selling price (in the normal course of business) of an inventory item
less the costs of completion and selling expenses.
TANGIBLE ASSETS
Cost
PetroFina follows the "successful efforts" method of accounting for the
cost of oil and gas exploration and production operations.
Lease acquisition costs related to properties held for oil, gas and mineral
exploration and production are capitalized when incurred. Unproved properties
with acquisition costs which are individually significant are assessed on a
property-by-property basis, and a loss is recognized, by provision of a
valuation allowance, when the assessment indicates an impairment in value.
Unproved properties with acquisition costs which are not individually
significant are generally aggregated and the portion of such costs estimated to
be non productive, based on historical experience, is amortized on an average
holding period basis.
Exploratory costs, excluding the costs of exploratory wells, are charged to
expense as incurred. Costs of drilling exploratory wells, including
stratigraphic test wells, are capitalized pending determination whether the
wells have found proved reserves which justify commercial development. If such
reserves are not found, the drilling costs are charged to exploration expenses.
All development costs related to proved oil and gas reserves are capitalized.
F-16
<PAGE> 79
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES -- (CONTINUED)
Interest is capitalized as a component of the cost of construction for
development projects in progress. Normal maintenance and repairs are charged to
expense as incurred. Renewals, betterments and major repairs that extend the
useful life or productivity of PP&E are capitalized and the assets replaced, if
any, are retired.
Impairment and Depreciation
For purposes of determining and recognizing impairment of long-lived
assets, the applicable carrying value is evaluated against the undiscounted
projection of net future pre-tax cash flows. The applicable grouping of assets
are based on the lowest practicable levels of identifiable cash flows,
consistent with the manner in which those assets are managed. If an impairment
exists, the carrying value is adjusted to the estimated fair value.
Assets to be disposed of are carried for at the lower of amortized cost or
fair value less cost to sell.
The capitalized costs related to producing activities, including tangible
and intangible costs, are amortized by field on the unit-of-production basis by
applying the ratio of produced oil and gas during the period to beginning of the
period proved developed oil and gas reserves. Estimated future restoration and
abandonment costs are accrued each period based on the associated
unit-of-production rate.
Depreciation of PP&E related to facilities other than producing properties
is provided using the straight-line method, over the asset's estimated useful
life. Typical useful lives of facilities are as follows :
<TABLE>
<S> <C>
- -- machinery & equipment 10 to 20 years
- -- buildings 20 years
- -- other 3 to 5 years
</TABLE>
INTANGIBLE ASSETS
Intangible assets primarily consist of patents, licences, goodwill, and
capitalized software development costs for internal use. Intangible assets are
depreciated over their estimated economic life, ranging generally from 5 years
to 20 years.
ENVIRONMENTAL EXPENDITURES
The estimated future costs for known environmental remediation requirements
are accrued when it is probable that a liability has been incurred and the
amount of remediation costs can be reasonably estimated. These amounts are the
undiscounted, future estimated costs under existing regulatory requirements and
using existing technology. Other environmental expenditures, principally
maintenance or preventive in nature, are recorded when expended and are expensed
or capitalized as appropriate.
INCOME TAXES
Income taxes are accounted for pursuant to the liability method. Under the
liability method, deferred tax assets and liabilities are measured as the tax
effected value of differences between the carrying values of assets and
liabilities for financial reporting and their tax basis. Deferred income tax
expense is the change during the year in the deferred tax assets and
liabilities. Effects of changes in tax laws and tax rates are recognized at the
date the tax law changes are enacted. Deferred taxes are not provided on
undistributed earnings of most subsidiaries as such earnings are deemed to be
indefinitely reinvested. A valuation allowance is recorded when necessary to
reduce deferred tax assets to the amount that is more likely than not to be
realized.
F-17
<PAGE> 80
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES -- (CONTINUED)
REVENUE RECOGNITION
Oil and gas sales are inclusive of production royalties paid in cash. Crude
oil and petroleum products trading activities are recorded in Sales and Costs of
sales when physical delivery takes place. Exchanges of crude oil and petroleum
products involving other oil companies are excluded from sales.
The Group uses the entitlement method for recording natural gas sales
revenues. Under the entitlement method, revenue is based on the Group's net
working interest in field production. Deliveries of natural gas in excess of the
company's working interest are recorded as liabilities while under-deliveries
are recorded as assets. Such differences are temporary in nature and have been
insignificant.
EARNINGS PER SHARE
Earnings per share is based on net income divided by the average number of
shares of common stock outstanding. When dilutive, stock warrants are included
in dilutive Earnings per share.
(2) SEGMENT DATA
The Group is a fully integrated energy company. The Group's principal lines
of business are crude oil and natural gas exploration and production and natural
gas marketing ("Upstream"), petroleum products refining, supply and
transportation and marketing ("Downstream"), chemicals manufacturing and
marketing ("Chemicals") and paint manufacturing and marketing ("Paints"). The
Group sells refined products in both the wholesale and retail markets. Natural
gas is sold primarily to marketers. Chemical products are primarily sold to
manufacturers of fiber, film, packaging and consumable products. Raw materials
are readily available and the Group is not dependent upon a single or limited
number of suppliers.
F-18
<PAGE> 81
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(2) SEGMENT DATA -- (CONTINUED)
Information regarding the Group's industry and geographic segments are as
follows:
<TABLE>
<CAPTION>
1997
--------------------------------------------------------------------
UPSTREAM DOWNSTREAM CHEMICALS PAINTS OTHER CONSOLIDATED
-------- ---------- --------- ------- ------- ------------
<S> <C> <C> <C> <C> <C> <C>
EUROPE(1)
- -----------------------------------------
OPERATING REVENUE:
Operating Revenue.................... $49,077 $462,637 $55,687 $31,452 $ 463 $599,316
Inter-segment........................ (29,736) (13,325) (4,511) -- (47,572)
Operating Revenue from Non
Affiliates......................... 19,341 449,312 51,176 31,452 463 551,744
Equity in Net Income of Affiliated
Companies.............................. 690 744 (152) 24 31 1,337
Operating Income/(Loss).................. 23,353 9,430 6,086 1,617 (1,638) 38,848
Identifiable Assets...................... 65,346 145,419 37,513 19,706 16,979 284,963
Depreciation, Depletion, and
Amortization........................... (8,289) (8,633) (3,207) (914) (460) (21,503)
Exploration Expenses..................... (2,203) (2,203)
Capital Expenditures..................... 15,250 8,397 3,230 1,014 256 28,147
NORTH AMERICA
- -----------------------------------------
OPERATING REVENUE:
Operating Revenue.................... 39,188 109,327 37,560 15 186,090
Inter-segment........................ (6,562) (3,636) (605) (10,803)
Operating Revenue from Non
Affiliates......................... 32,626 105,691 36,955 15 175,287
Equity in Net Income of Affiliated
Companies.............................. 86 (2) (35) 49
Operating Income/(Loss).................. 1,935 2,575 4,353 (878) 7,985
Identifiable Assets...................... 30,342 49,607 30,931 7,775 118,655
Depreciation, Depletion, and
Amortization........................... (3,464) (2,203) (1,238) (295) (7,200)
Exploration Expenses..................... (2,151) (2,151)
Capital Expenditures..................... 7,766 1,695 5,753 299 15,513
CONSOLIDATED
- -----------------------------------------
OPERATING REVENUE:
Operating Revenue.................... 88,265 571,964 93,247 31,452 478 785,406
Inter-segment........................ (36,298) (16,961) (5,116) (58,375)
Operating Revenue from Non
Affiliates......................... 51,967 555,003 88,131 31,452 478 727,031
Equity in Net Income of Affiliated
Companies.............................. 776 742 (187) 24 31 1,386
Operating Income/(Loss).................. 25,288 12,005 10,439 1,617 (2,516) 46,833
Identifiable Assets...................... 95,688 195,026 68,444 19,706 24,754 403,618
Depreciation, Depletion, and
Amortization........................... (11,753) (10,836) (4,445) (914) (755) (28,703)
Exploration Expenses..................... (4,354) (4,354)
Capital Expenditures..................... 23,016 10,092 8,983 1,014 555 43,660
</TABLE>
- ---------------
(1) Europe includes Europe and other parts of the world outside North America
for Upstream, Downstream and Other segments. Other parts of the world
represent less than 1% of the operating revenues, profit, and total assets
of the respective segment.
F-19
<PAGE> 82
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(2) SEGMENT DATA -- (CONTINUED)
<TABLE>
<CAPTION>
1996
------------------------------------------------------------------
EUROPE(1) UPSTREAM DOWNSTREAM CHEMICALS PAINTS OTHER CONSOLIDATED
--------- -------- ---------- --------- ------ ----- ------------
<S> <C> <C> <C> <C> <C> <C>
OPERATING REVENUE:
Operating Revenue........................ 41,960 402,943 46,567 29,439 1,021 521,930
Inter-segment............................ (25,932) (10,357) (2,964) (3) (39,256)
Operating Revenue from Non Affiliates.... 16,028 392,586 43,603 29,436 1,021 482,674
Equity in Net Income of Affiliated
Companies................................ 892 814 7 20 (248) 1,485
Operating Income/(Loss).................... 21,996 5,697 4,184 1,207 (1,851) 31,233
Identifiable Assets........................ 57,702 141,749 35,712 18,717 19,725 273,605
Depreciation, Depletion, and
Amortization............................. 6,605 7,258 2,999 830 742 18,434
Exploration Expenses....................... 1,775 1,775
Capital Expenditures....................... 12,945 6,625 1,947 1,151 1,009 23,677
NORTH AMERICA
- -------------------------------------------
OPERATING REVENUE:
Operating Revenue........................ 23,252 93,418 31,837 -- 12 148,519
Inter-segment............................ (5,191) (3,400) (457) -- -- (9,048)
Operating Revenue from Non Affiliates.... 18,061 90,018 31,380 12 139,471
Equity in Net Income of Affiliated
Companies................................ -- 3 (22) -- -- (19)
Operating Income/(Loss).................... 2,169 (502) 7,153 -- (665) 8,155
Identifiable Assets........................ 22,703 43,168 22,489 -- 4,823 93,183
Depreciation, Depletion, and
Amortization............................. 2,320 1,879 999 -- 143 5,341
Exploration Expenses....................... 1,255 -- -- -- -- 1,255
Capital Expenditures....................... 5,019 2,346 1,740 -- 360 9,465
CONSOLIDATED
- -------------------------------------------
OPERATING REVENUE:
Operating Revenue........................ 65,212 496,361 78,404 29,439 1,033 670,449
Inter-segment............................ (31,123) (13,757) (3,421) (3) -- (48,304)
Operating Revenue from Non Affiliates.... 34,089 482,604 74,983 29,436 1,033 622,145
Equity in Net Income of Affiliated
Companies................................ 892 817 (15) 20 (248) 1,466
Operating Income/(Loss).................... 24,165 5,195 11,337 1,207 (2,516) 39,388
Identifiable Assets........................ 80,405 184,917 58,201 18,717 24,548 366,788
Depreciation, Depletion, and
Amortization............................. 8,925 9,137 3,998 830 885 23,775
Exploration Expenses....................... 3,030 3,030
Capital Expenditures....................... 17,964 8,971 3,687 1,151 1,369 33,142
</TABLE>
- ---------------
(1) Europe includes Europe and other parts of the world outside North America
for Upstream, Downstream and Other segments. Other parts of the world
represent less than 1% of the operating revenues, profit, and total assets
of the respective segment.
F-20
<PAGE> 83
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(2) SEGMENT DATA -- (CONTINUED)
<TABLE>
<CAPTION>
1995
------------------------------------------------------------------
EUROPE(1) UPSTREAM DOWNSTREAM CHEMICALS PAINTS OTHER CONSOLIDATED
--------- -------- ---------- --------- ------ ----- ------------
<S> <C> <C> <C> <C> <C> <C>
OPERATING REVENUE:
Operating Revenue........................ 34,731 360,654 49,371 28,390 1,305 474,451
Inter-segment............................ (18,470) (12,452) (2,524) -- (333) (33,779)
Operating Revenue from Non Affiliates.... 16,261 348,202 46,847 28,390 972 440,672
Equity in Net Income of Affiliated
Companies................................ 484 600 359 15 (168) 1,290
Operating Income/(Loss).................... 13,841 348 10,438 854 (2,170) 23,311
Identifiable Assets........................ 48,174 136,636 35,893 17,813 19,202 257,718
Depreciation, Depletion, and
Amortization............................. 6,899 6,518 2,881 838 733 17,869
Exploration Expenses....................... 2,680 -- -- -- -- 2,680
Capital Expenditures....................... 9,801 6,572 4,604 745 795 22,517
------- ------- ------ ------ ------ -------
NORTH AMERICA
- -------------------------------------------
OPERATING REVENUE:
Operating Revenue........................ 13,867 81,034 30,570 -- 14 125,485
Inter-segment............................ (3,217) (3,996) (220) -- -- (7,433)
Operating Revenue from Non Affiliates.... 10,650 77,038 30,350 -- 14 118,052
Equity in Net Income of Affiliated
Companies................................ 48 1 (18) 24 55
Operating Income/(Loss).................... (441) (113) 8,576 -- (545) 7,477
Identifiable Assets........................ 18,007 36,868 17,076 -- 4,223 76,174
Depreciation, Depletion, and
Amortization............................. 1,778 2,080 701 -- 105 4,664
Exploration Expenses....................... 1,506 -- -- -- -- 1,506
Capital Expenditures....................... 2,487 1,246 3,389 -- 213 7,335
------- ------- ------ ------ ------ -------
CONSOLIDATED
- -------------------------------------------
OPERATING REVENUE:
Operating Revenue........................ 48,598 441,688 79,941 28,390 1,319 599,936
Inter-segment............................ (21,687) (16,448) (2,744) -- (333) (41,212)
Operating Revenue from Non Affiliates.... 26,911 425,240 77,197 28,390 986 558,724
Equity in Net Income of Affiliated
Companies................................ 532 601 341 15 (144) 1,345
Operating Income/(Loss).................... 13,400 235 19,014 854 (2,715) 30,788
Identifiable Assets........................ 66,181 173,504 52,969 17,813 23,425 333,892
Depreciation, Depletion, and
Amortization............................. 8,677 8,598 3,582 838 838 22,533
Exploration Expenses....................... 4,186 -- -- -- -- 4,186
Capital Expenditures....................... 12,288 7,818 7,993 745 1,008 29,852
</TABLE>
- ---------------
(1) Europe includes Europe and other parts of the world outside North America
for Upstream, Downstream and Other segments. Other parts of the world
represent less than 1% of the operating revenues, profit, and total assets
of the respective segment.
(3) RESEARCH COSTS
Research costs incurred and expensed amounted to BEF 3,230 million in 1997,
BEF 3,062 million in 1996 and 2,883 million in 1995.
F-21
<PAGE> 84
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(4) INTANGIBLE ASSETS
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Patents & licences.......................................... 2,758 2,760 2,279
Customer goodwill........................................... 2,501 2,159 2,310
Other intangible assets..................................... 3,832 3,338 3,572
------ ------ ------
9,091 8,257 8,161
Accumulated amortization.................................... (6,825) (6,260) (6,181)
------ ------ ------
2,266 1,997 1,980
</TABLE>
(5) TANGIBLE ASSETS
A summary of tangible assets follows:
<TABLE>
<CAPTION>
1997 1996 1995
-------- -------- --------
<S> <C> <C> <C>
Land & buildings............................................ 48,151 44,936 39,901
Plant & equipment........................................... 242,211 223,800 207,602
Proved oil & gas properties................................. 168,420 147,725 132,356
Unproved oil & gas properties............................... 17,923 16,800 14,408
Other tangible assets....................................... 13,042 9,903 8,876
Assets under construction................................... 33,371 17,002 9,366
-------- -------- --------
523,118 460,166 412,509
Accumulated depreciation, depletion and amortization........ (287,963) (248,999) (217,354)
-------- -------- --------
235,155 211,167 195,155
</TABLE>
Capitalized interest included in capital expenditures amounted to BEF 1,616
million in 1997, to BEF 863 million in 1996 and to BEF 440 million in 1995.
(6) FINANCIAL ASSETS
<TABLE>
<CAPTION>
1997 1996 1995
----- ----- -----
<S> <C> <C> <C>
Companies accounted for under equity method................. 5,208 4,107 4,589
Other companies............................................. 1,339 2,157 1,409
Loans....................................................... 332 333 589
----- ----- -----
6,879 6,597 6,587
</TABLE>
(7) OTHER ASSETS
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ -----
<S> <C> <C> <C>
Deferred tax assets......................................... 1,556 2,079 1,761
Other long term receivables................................. 10,238 9,193 7,689
------ ------ -----
11,794 11,272 9,450
</TABLE>
F-22
<PAGE> 85
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(8) STOCKS
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
A summary of inventories follows:
-- Petroleum products..................................... 28,934 27,581 24,121
-- Chemicals products and paints.......................... 15,788 13,811 13,970
-- Other products and materials........................... 6,837 6,783 6,942
------ ------ ------
51,559 48,175 45,033
</TABLE>
The carrying value of crude oil, finished petroleum products and chemical
products inventories accounted for using the LIFO method amounted to BEF 41.4
billion at December 31, 1997, BEF 38.2 billion at December 31, 1996 and BEF 34.8
billion at December 31, 1995.
The excess of replacement cost of these inventories over LIFO was BEF 1.1
billion, BEF 6.2 billion and BEF 1.3 billion for the same periods.
(9) TRADE DEBTORS
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Trade receivables........................................... 76,325 71,885 61,178
Write-downs on trade receivables............................ (2,785) (2,817) (2,500)
------ ------ ------
73,540 69,068 58,678
</TABLE>
(10) OTHER DEBTORS
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Taxes & withholding taxes to be recovered................... 2,301 2,373 2,608
Deferred tax assets......................................... 2,877 933 823
Deferred charges and accrued income......................... 3,144 2,743 3,109
Others...................................................... 3,805 4,855 3,783
------ ------ ------
12,127 10,904 10,323
</TABLE>
(11) INCOME TAX PAYABLE
<TABLE>
<CAPTION>
1997 1996 1995
------- ------- -------
<S> <C> <C> <C>
At the beginning of the year................................ 10,130 6,346 6,324
Current income tax expense.................................. 16,839 16,296 12,150
Taxes paid during the year.................................. (18,297) (13,070) (12,016)
Translation effects......................................... 243 561 (111)
Other....................................................... -- (3) (1)
------- ------- -------
8,915 10,130 6,346
</TABLE>
F-23
<PAGE> 86
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(12) OTHER CREDITORS
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Other taxes (VAT)........................................... 3,754 3,215 2,705
Accrued expenses and deferred income........................ 5,573 6,538 5,964
Excise duties............................................... 12,992 13,503 13,125
Salary and social benefits.................................. 3,648 3,755 3,358
Other....................................................... 11,020 10,037 10,210
------ ------ ------
36,987 37,048 35,362
</TABLE>
(13) CURRENT AND LONG TERM FINANCIAL DEBTS
SHORT TERM BORROWINGS
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Bank Obligations............................................ 24,060 27,439 19,514
Commercial Paper............................................ 1,587 5,812 8,296
Other....................................................... 32 885 769
------ ------ ------
25,679 34,136 28,579
Current portion of Long Term Debt........................... 4,507 1,507 6,026
------ ------ ------
30,186 35,643 34,605
</TABLE>
Weighted average interest rates on outstanding borrowings at December 31,
1997, 1996 and 1995 were 6.33%, 5.84% and 6.09% respectively.
LONG TERM BORROWINGS
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Bonds and Notes (rates from 3.5% to 10% maturing through
2005)..................................................... 23,386 35,566 36,459
Bank Obligations (rates from 3.58% to 10.75% maturing
through 2008)............................................. 39,543 12,768 11,657
Capital Lease Obligations................................... 1,388 899 968
Other....................................................... 166 1,600 1,674
------ ------ ------
64,483 50,833 50,758
Less current portion........................................ (4,507) (1,507) (6,026)
------ ------ ------
59,976 49,326 44,732
</TABLE>
F-24
<PAGE> 87
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(13) CURRENT AND LONG TERM FINANCIAL DEBTS -- (CONTINUED)
LONG TERM BORROWINGS BY CURRENCY
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Excludes the effects of currency swap transactions:
US Dollars.................................................. 49,221 31,651 25,412
BEF......................................................... 9,738 11,254 12,999
DEM (German Mark)........................................... 27 6,186 8,530
NLG (Netherlands Gulden).................................... 4,052 222 15
Other currencies............................................ 1,445 1,520 3,802
------ ------ ------
64,483 50,833 50,758
</TABLE>
As of December 31, 1997 the Group had committed and unused credit
facilities with various banks in various currencies totaling BEF 52,374 million.
Commitment fees associated with these credit facilities range from 0.07% to
0.20% on undrawn amounts. The Group intends to use borrowings under these
facilities to finance the repayment of BEF 26,630 million of commercial paper
classified as long term debt at December 31, 1997.
Fixed and variable rate debt is borrowed in the most cost-effective means
to manage risk arising from fluctuations in interests rates. Petrofina's
interest rate swaps convert BEF 23.9 billion of variable rate debt to an average
fixed rate of 7.06%, and BEF 8.5 billion of fixed rate debt to an average
variable rate of 6.12% as of December 31, 1997.
The aggregate maturities of long term borrowings (in BEF million) are as
follows:
<TABLE>
<CAPTION>
YEAR LONG-TERM BORROWINGS
---- --------------------
<S> <C>
1998..................................................... BEF 4,507 million
1999..................................................... BEF 2,840 million
2000..................................................... BEF 12,524 million
2001..................................................... BEF 6,231 million
2002..................................................... BEF 14,835 million
2003 and later........................................... BEF 23,546 million
</TABLE>
Certain notes and credit facilities contain provisions that limit mergers
and sales of assets, limit the incurrence of indebtedness and restrict payments
within subsidiaries of the Group.
No material amounts of current or long term debt are collateralized by
Group assets.
F-25
<PAGE> 88
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(14) FINANCIAL INSTRUMENTS
Amounts related to Petrofina's financial instruments were as follows:
<TABLE>
<CAPTION>
AS OF DECEMBER 31,
---------------------------------------------------------------
1997 1996 1995
----------------- ----------------- -----------------
CARRYING FAIR CARRYING FAIR CARRYING FAIR
AMOUNT VALUE AMOUNT VALUE AMOUNT VALUE
-------- ------ -------- ------ -------- ------
<S> <C> <C> <C> <C> <C> <C>
BALANCE SHEET FINANCIAL INSTRUMENTS:
Marketable securities............... 6,640 6,640 4,885 4,885 3,844 3,844
Long term debt...................... 64,483 66,193 50,833 53,143 50,758 53,531
DERIVATIVE INSTRUMENTS:
Interest rate swaps................. (216) (753) 99 (510) 350 (993)
Currency swaps...................... (99) (123) (186) (265) (199) 171
Forward foreign exchange
contracts......................... 107 107 (175) (175) (108) (108)
Commodity contracts................. 12 12 208 208 2 2
</TABLE>
Petrofina's notional amount of debt covered under interest rate swaps
totaled approximately BEF 32.4 billion, BEF 26.7 billion and BEF 22.3 billion,
and under currency swaps totaled approximately BEF 4.3 billion BEF 7.1 billion
and BEF 9.1 billion at December 31, 1997, 1996, and 1995, respectively. Amounts
to be paid or received under these agreements are accrued on the balance sheet
over the life of the swap agreements. The fair value of the swap agreements are
not recognized in the consolidated financial statements since they are accounted
for as hedges of the underlying debt instruments.
For the periods ended December 31, 1997, 1996 and 1995, PetroFina had
forward foreign exchange buy contracts of BEF 49.2 billion, BEF 34.3 billion and
BEF 23.8 billion, respectively, principally denominated in Belgian franc and US
dollar, and sell contracts of BEF 49.2 billion, BEF 34.5 billion and BEF 23.9
billion, respectively, principally denominated in German mark, French franc,
Norwegian krone, and British pound and US dollar. Because these contracts are of
a short term nature (principally less than six months) their fair value and
carrying value are approximately the same.
Also for the periods ended December 31, 1997, 1996 and 1995, the Company
had crude oil and refined products futures and forward buy contracts of notional
amounts of BEF 1.5 billion, BEF 4.1 billion and BEF 1.4 billion, respectively;
and sell contracts of notional amounts of BEF 2.3 billion, BEF 1.6 billion and
BEF 0.2 billion, respectively. These contracts are recorded at fair value.
Natural gas contracts are insignificant at December 31, 1997, 1996 and 1995.
The carrying value of cash and cash equivalents, accounts receivable, and
accounts payable approximated their fair values due to the short term maturities
of these instruments. The estimated fair values of other financial instruments,
including debt and risk management instruments summarized above, have been
determined using available market information and valuation methodologies,
primarily discounted cash flow analysis.
(15) INCOME TAXES
Current tax expense for 1997, 1996 and 1995 was BEF 16,839 million, BEF
16,296 million and BEF 12,150 million, respectively. Deferred tax expense for
1997, 1996 and 1995 was BEF 2,692 million, BEF 1,382 million and BEF 942
million, respectively.
F-26
<PAGE> 89
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(15) INCOME TAXES -- (CONTINUED)
THE COMPONENTS OF DEFERRED INCOME TAX EXPENSE FOR EACH YEAR WERE AS
FOLLOWS:
<TABLE>
<CAPTION>
FOR THE PERIOD ENDED
DECEMBER 31,
---------------------
1997 1996 1995
------ ----- ----
(in BEF million)
<S> <C> <C> <C>
Deferred tax expense, excluding items below................. 3,489 251 (512)
Benefits of tax loss carryforwards.......................... 991 482 832
Effect of foreign tax rate changes.......................... (1,257) -- --
Net change in valuation allowance........................... (531) 649 622
------ ----- ----
Deferred income tax expense................................. 2,692 1,382 942
</TABLE>
ACTUAL INCOME TAX EXPENSE DIFFERS FROM THE EXPECTED INCOME TAX EXPENSE
USING THE BELGIAN STATUTORY INCOME TAX RATE AS FOLLOWS:
<TABLE>
<CAPTION>
FOR THE PERIOD ENDED
DECEMBER 31,
------------------------
1997 1996 1995
------ ------ ------
(in BEF million)
<S> <C> <C> <C>
Income before tax and minority interest..................... 42,237 34,322 25,617
Expected income tax at statutory tax rate of 40.17%......... 16,967 13,787 10,290
-- foreign tax rate differences........................ 6,915 5,979 4,474
-- uplift benefit(1)................................... (1,121) (1,220) (667)
-- non deductible expenses............................. 1,000 674 916
-- tax free income..................................... (2,195) (2,092) (2,619)
-- change in valuation allowance....................... (531) 649 622
-- effect of foreign tax rate changes(2)............... (1,257) -- --
-- other............................................... (247) (99) 76
------ ------ ------
Total income tax expense.................................... 19,531 17,678 13,092
</TABLE>
- ---------------
(1) Uplift is a special deduction allowed against revenues from oil and gas
activities on the Norwegian continental shelf.
(2) Effect primarily of tax rates reduction in the UK and in Italy.
F-27
<PAGE> 90
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(15) INCOME TAXES -- (CONTINUED)
THE DEFERRED INCOME TAX ASSETS AND LIABILITIES ARE AS FOLLOWS:
<TABLE>
<CAPTION>
FOR THE PERIOD ENDED DECEMBER 31,
---------------------------------
1997 1996 1995
--------- --------- ---------
(in BEF million)
<S> <C> <C> <C>
Deferred income tax assets:
-- tax loss carryforwards.............................. 8,273 9,431 9,473
-- deferred uplift (1)................................. 2,353 2,020 1,290
-- provisions and accrued liabilities.................. 2,114 3,804 3,737
-- investment deductions............................... 378 495 739
-- AMT credits (2)..................................... 4,763 3,638 1,795
--- other.............................................. 515 377 85
Valuation allowance......................................... (6,872) (8,658) (7,605)
------- ------- -------
Net deferred income tax assets.............................. 11,524 11,107 9,514
Deferred income tax liabilities :
-- PP&E related(3)..................................... (29,690) (25,423) (20,510)
-- untaxed reserves.................................... (5,041) (6,052) (6,549)
------- ------- -------
Total deferred income tax liabilities....................... (34,731) (31,475) (27,059)
Net deferred income tax liability........................... (23,207) (20,368) (17,545)
</TABLE>
- ---------------
(1) uplift is a special deduction allowed against revenues from oil and gas
activities on the Norwegian continental shelf
(2) AMT credits relate to the alternative minimum tax system in the United
States and are credit carryforwards available to reduce future regular
income taxes
(3) primarily related to depreciation and depletion rate differences
AT THE END OF 1997, PETROFINA HAD TAX LOSS CARRYFORWARDS OF BEF 19,196
MILLION PRIMARILY IN BELGIUM, FRANCE, GERMANY AND THE USA. CARRYFORWARD AMOUNTS
(WHICH ARE NOT RATE EFFECTED) EXPIRE AS FOLLOWS:
<TABLE>
<CAPTION>
AS OF DECEMBER 31, 1997
-----------------------
(in BEF million)
<S> <C>
1998........................................................ 1,467
1999........................................................ 395
2000........................................................ 149
2001........................................................ 20
2002........................................................ 21
After 2002.................................................. 3,937
Without expiration.......................................... 13,207
</TABLE>
(16) STATEMENT OF INCOME
Net income is affected by transactions that are not representative of the
Group's current operations.
These transactions, defined as "non recurrent elements" which can affect
the comparability of annual operating results, are summarized in the table
below.
F-28
<PAGE> 91
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(16) STATEMENT OF INCOME -- (CONTINUED)
NON RECURRENT ELEMENTS (IN BEF BILLION)
<TABLE>
<CAPTION>
1997 1996 1995
---- ---- ----
<S> <C> <C> <C>
UPSTREAM
a) Europe
Impairment test Ann/Alison............................... (0.5)
b) North America
Capital gains on assets sold............................. 0.3 0.2
DOWNSTREAM
a) Europe
Inventory (write-down), write-back....................... (0.1) 0.3 0.3
Accelerated depreciation................................. (0.2)
Provisions for site restoration.......................... (0.1)
Capital gains on assets sold............................. 1.0
b) North America
Inventory (write-down), write-back....................... (0.2)
CHEMICALS
Europe
Capital gains on assets sold................................ 0.3
PAINTS
Provisions for litigation................................... (0.1)
Provisions for site restoration............................. (0.1)
Accelerated depreciation.................................... (0.1)
EARLY RETIREMENT COSTS...................................... (0.9) (1.1) (0.9)
TAX
Tax on non recurrent elements............................... 0.1 (0.2)
Influence, on deferred taxes, of tax rate reduction in Italy
and U.K................................................... 1.3
---- ---- ----
(0.1) (0.6)
</TABLE>
b) PERSONNEL COSTS
<TABLE>
<CAPTION>
PROPORTIONAL
FULL CONSOLIDATION CONSOLIDATION TOTAL
------------------------ --------------------- ------------------------
1997 1996 1995 1997 1996 1995 1997 1996 1995
------ ------ ------ ----- ----- ----- ------ ------ ------
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C>
1. Personnel employed (number of employees)
Operational employees........... 4,466 3,923 3,948 443 438 512 4,909 4,361 4,460
Administrative employees........ 5,371 4,896 4,699 282 286 220 5,653 5,182 4,919
Management...................... 3,878 3,807 3,992 235 238 282 4,113 4,045 4,274
------ ------ ------ ----- ----- ----- ------ ------ ------
13,715 12,626 12,639 960 962 1,014 14,675 13,588 13,653
2. Personnel costs (in BEF million)
Salaries & direct social
benefits...................... 21,747 19,029 18,658 1,756 1,650 1,558 23,503 20,679 20,216
Employee's social security
contributions................. 4,534 4,457 4,444 508 497 504 5,042 4,954 4,948
Other payroll costs............. 1,869 1,592 1,741 240 237 214 2,109 1,829 1,955
------ ------ ------ ----- ----- ----- ------ ------ ------
28,150 25,078 24,843 2,504 2,384 2,276 30,654 27,462 27,119
</TABLE>
F-29
<PAGE> 92
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(16) STATEMENT OF INCOME -- (CONTINUED)
c) INTEREST EXPENSE
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Interest expense on interest-bearing debt................... (6,307) (6,448) (6,519)
Capitalized interest relating to assets under
construction.............................................. 1,616 863 440
------ ------ ------
(4,691) (5,585) (6,079)
</TABLE>
d) OTHER FINANCIAL INCOME NET
<TABLE>
<CAPTION>
1997 1996 1995
------ ----- ----
<S> <C> <C> <C>
Income relating to marketable securities, cash and financial
loans..................................................... 951 1,026 934
Other financial income...................................... 527 199 270
Financial transaction costs................................. (1,000) (568) (303)
Exchange rate gain (loss)................................... (383) (138) 7
------ ----- ----
95 519 908
</TABLE>
(17) COMMITMENTS
PetroFina occupies certain marketing and production facilities and uses
certain equipment under leasing arrangements. Total rental expense incurred was
BEF 5,419 million, 4,782 million and BEF 4,527 million for 1997, 1996 and 1995.
Future minimum rental commitments as at December 31, 1997, under operating
leases having non cancellable lease terms in excess of one year are detailed in
the following schedule. Sublease rentals, contingent rentals, and capital lease
obligations are not significant.
LEASE EXPENSE
<TABLE>
<CAPTION>
(in BEF million)
<S> <C>
1998......................................... 2,851
1999......................................... 2,477
2000......................................... 2,081
2001......................................... 1,686
2002......................................... 1,389
Thereafter................................... 5,744
</TABLE>
The Group has contractual commitments to spend approximately BEF 3,395
million related to construction in progress at various locations at December 31,
1997.
The Group provided various bank guarantees to both third parties and
non-consolidated companies for BEF 3,355, BEF 3,362 million and BEF 6,720
million at December 31, 1997, 1996 and 1995, respectively. The fair value is not
readily determinable for these guarantees.
The Group receives and grants certain customs guarantees with third
parties. Guarantees granted and received amount to BEF 19,870 million, BEF
19,441 million and BEF 13,353 million and BEF 10,744 million BEF 9,799 million
and BEF 12,782 million for the years ended December 31, 1997, 1996 and 1995,
respectively.
At December 31, 1996 and 1995 the Group factored with recourse accounts
receivable amounting to BEF 2,500 million.
F-30
<PAGE> 93
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(18) CONTINGENCIES
In its normal course of business, the Group is involved in various legal,
fiscal and environmental proceedings. Management is of the opinion that the
result of these proceedings will not have a material impact on the Group's
financial position or results of operations.
The Group is subject to legislation regarding environmental laws and
regulations. These regulations regulate the discharge of materials into the
environment and may require the Group to incur future obligations to investigate
the effects of the release or disposal of certain petroleum, chemical and
mineral substances at various sites; to remediate or restore these sites; to
compensate others for damage to property and natural resources and for
remediation and restoration costs.
At December 31, 1997, 1996 and 1995, the Group's accrued environmental
liabilities include BEF 4,368 million, BEF 3,717 million and BEF 3,119 million,
respectively, for dismantlement and removal costs primarily related to the
Group's interests in worldwide offshore production facilities. These costs are
accrued by the Group on the units-of-production method.
At December 31, 1997, 1996 and 1995, the Group's recorded accrued
liabilities for environmental remediation efforts were BEF 9,575 million, BEF
9,474 million and BEF 8,940 million, respectively. At December 31, 1997, 1996
and 1995, accrued environmental costs include BEF 684 million, BEF 625 million
and BEF 614 million, respectively, for remediation sites in the United States
where the Group has been named as a Potentially Responsible Party under United
States Superfund legislation.
The Group has determined these liabilities based on judgments made as to
the extent of and mechanisms for environmental remediation and the current
levels of costs for equipment and services. While there are certain assumptions
inherent in this process and changes to such assumptions could produce ranges in
the amount of expected remediation costs, it is PetroFina's belief that the
amounts accrued and disclosed represent the most probable amount. The likelihood
of material losses in excess of recorded amounts at known remediation sites is
remote.
(19) EMPLOYEE BENEFIT PLANS
Pension plans:
The Group maintains a number of defined benefit pension plans covering most
categories of employees. Plan benefits are generally based on employees' years
of service and latest salaries earned. The plans are administered by independent
pension trusts, insurance companies or internally. Funded pension plan assets
are primarily invested in fixed income securities, real estate, and marketable
equity securities. Actuarial values are
F-31
<PAGE> 94
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(19) EMPLOYEE BENEFIT PLANS -- (CONTINUED)
determined by independent experts. The method used for the determination of the
annual service cost and projected benefits obligations is the projected unit
credit method.
<TABLE>
<CAPTION>
BELGIAN NON BELGIAN
------------------------------ --------------------------------
PLAN ASSETS EXCEEDS ABO ABO EXCEEDS PLAN ASSETS
AS OF DECEMBER 31, AS OF DECEMBER 31,
------------------------------ --------------------------------
1997 1996 1995 1997 1996 1995
-------- -------- -------- -------- ---------- --------
<S> <C> <C> <C> <C> <C> <C>
RECONCILIATION OF FUNDED STATUS
Pension benefit obligation:
-- Vested benefit obligation......... (5,403.7) (5,151.0) (4,930.0) (3,581.4) (3,331.3) (3,252.7)
-- Non vested........................ (505.5) (452.5) (429.6) (123.3) (109.2) (120.3)
-- Accumulated benefit obligation
(ABO).............................. (5,909.2) (5,603.5) (5,359.6) (3,704.7) (3,440.5) (3,373.0)
-- Effect of future salaries......... (2,650.1) (2,780.7) (2,649.9) (219.2) (227.7) (243.2)
-- Projected benefit obligation...... (8,559.3) (8,384.2) (8,009.5) (3,923.9) (3,668.2) (3,616.2)
Plan assets at fair value............. 9,323.1 8,781.7 8,262.2 0.0 0.0 0.0
Funded status......................... 763.8 397.5 252.7 (3,923.9) (3,668.2) (3,616.2)
Unrecognized net transition obligation
(assets)............................. (145.8) (165.3) (184.8) 300.7 353.4 403.8
Unrecognized prior service costs...... 39.5 0.0 0.0 20.1 17.5 18.3
Unrecognized net loss/(gain).......... (864.0) (383.6) (145.3) (131.8) (130.3) (151.9)
Additional liability.................. 0.0 (1.6) -- (41.4) (26.5)
Prepaid/(accrued) pension costs....... (206.5) (151.4) (79.0) (3,734.9) (3,469.0) (3,372.5)
PENSION EXPENSE
Service cost without interest......... 311.5 317.9 285.1 62.6 56.4 70.1
Interest cost......................... 606.5 566.5 579.8 246.9 229.4 226.2
Actual return of assets
-- Expected return................... (672.1) (584.0) (547.4) 0.0 0.0 0.0
-- Additional return................. 2.9 (269.0) (504.9) 0.0 0.0 0.0
-- Total actual return............... (669.2) (853.0) (1,052.3) 0.0 0.0 0.0
Net amortization and deferral......... (47.8) 249.5 485.4 52.2 46.9 47.8
Net periodic pension expense
(benefit)............................ 201.0 280.9 298.0 361.7 332.7 344.1
ASSUMPTIONS
Discount rate......................... 7% 7% 7% 6 to 8.5%
Assumed rate of return of plan
assets............................... 8.25% 8.25% 8.25%
Salary increase....................... 5% 5% 5% 2.0 to 6.5%
Inflation rate........................ 2.5% 3% 3% 2.0 to 4.5%
<CAPTION>
NON BELGIAN
----------------------------------
PLAN ASSETS EXCEEDS ABO
AS OF DECEMBER 31,
----------------------------------
1997 1996 1995
--------- ---------- ---------
<S> <C> <C> <C>
RECONCILIATION OF FUNDED STATUS
Pension benefit obligation:
-- Vested benefit obligation......... (21,629.5) (15,885.0) (13,504.6)
-- Non vested........................ (552.7) (436.6) (398.9)
-- Accumulated benefit obligation
(ABO).............................. (22,182.2) (16,321.6) (13,903.5)
-- Effect of future salaries......... (3,361.0) (2,495.2) (2,179.5)
-- Projected benefit obligation...... (25,543.2) (18,816.8) (16,083.0)
Plan assets at fair value............. 33,453.7 25,877.5 21,345.1
Funded status......................... 7,910.5 7,060.7 5,262.1
Unrecognized net transition obligation
(assets)............................. (2,015.0) (2,078.7) (2,163.5)
Unrecognized prior service costs...... 58.3 55.1 56.5
Unrecognized net loss/(gain).......... (876.3) (1,427.4) (366.4)
Additional liability.................. -- 0.0 0.0
Prepaid/(accrued) pension costs....... 5,077.5 3,609.7 2,788.7
PENSION EXPENSE
Service cost without interest......... 603.2 556.6 423.8
Interest cost......................... 1,561.0 1,359.4 1,165.3
Actual return of assets
-- Expected return................... (2,505.6) (2,084.5) (1,709.1)
-- Additional return................. (2,424.3) (1,164.0) (1,464.4)
-- Total actual return............... (4,929.9) (3,248.5) (3,173.5)
Net amortization and deferral......... 2,030.5 873.6 1,201.7
Net periodic pension expense
(benefit)............................ (735.2) (458.9) (382.7)
ASSUMPTIONS
Discount rate......................... 6 to 8.25%
Assumed rate of return of plan
assets............................... 7 to 11%
Salary increase....................... 2.5 to 6.5%
Inflation rate........................ 2.0 to 4.5%
</TABLE>
Postretirement Plans:
In addition to providing pension benefits, certain health care and life
insurance benefits are provided to active and certain retired employees who meet
eligibility requirements defined in plan documents. The health care benefits in
excess of certain limits and the life insurance benefits are insured. The costs
of providing these benefits for active employees was BEF 291 million in 1997,
BEF 267 million in 1996 and BEF 254 million in 1995.
F-32
<PAGE> 95
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(19) EMPLOYEE BENEFIT PLANS -- (CONTINUED)
A summary of the postretirement plan's funded status and amounts recognized
in the consolidated balance sheet follows:
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------
1997 1996 1995
----- ----- -----
<S> <C> <C> <C>
ACCUMULATED POSTRETIREMENT BENEFIT OBLIGATION:
-- retirees............................................... 1,403 1,215 1,237
-- fully eligible active plan participants................ 120 97 88
-- other active plan participants......................... 863 612 564
----- ----- -----
2,386 1,924 1,889
-- unrecognized net gain (loss)........................... (73) 39 (147)
-- unrecognized prior service cost........................ 7 6 6
----- ----- -----
Accrued postretirement benefit cost......................... 2,320 1,969 1,748
NET PERIODIC POSTRETIREMENT BENEFIT COST:
-- service cost........................................... 45 41 30
-- interest cost.......................................... 161 144 151
-- amortization of unrecognized prior service costs....... (1) (1) (1)
----- ----- -----
205 184 180
</TABLE>
The health care cost annual trend rate assumed for 1997, for pre-65 and
post-65 years of age, was 7.0% and 6.79%, respectively. For 1998, this rate was
assumed to be 6.55% and 6.43%, respectively, and gradually decrease to 6% and
5%, respectively. The health care cost trend rate has a significant effect on
the amounts reported. Increasing the trend rate by one percentage point in each
year would increase the accumulated postretirement benefit obligation by BEF 181
million as of December 31, 1997 and net periodic postretirement benefit cost by
BEF 12 million for 1997.
The weighted average discount rate used in determining the accumulated
postretirement benefit obligation was 7.25%, 7.75% and 7.5% at December 31,
1997, 1996 and 1995, respectively. The effect of this change was an increase of
BEF 291 million, a decrease of BEF 52 million in 1996 and an increase of BEF 229
million in 1995 respectively, on the accumulated postretirement benefit
obligation.
(20) OTHER LONG TERM LIABILITIES
<TABLE>
<CAPTION>
1997 1996 1995
------ ------ ------
<S> <C> <C> <C>
Provisions for site restoration............................. 9,575 9,474 8,940
Pensions and similar commitments............................ 8,170 7,484 7,132
Other....................................................... 7,811 8,098 8,144
------ ------ ------
25,556 25,056 24,216
</TABLE>
(21) COMMON STOCK AND WARRANTS
PetroFina S.A. had issued and outstanding 23,420,432, 23,252,863 and
23,252,451 ordinary shares as at December 31, 1997, 1996 and 1995. The average
number of shares used to calculate earnings per share was 23,350,612, 23,252,764
and 23,252,414 for 1997, 1996 and 1995, respectively on a basic and dilutive
basis.
The Company issued 1,162,611 warrants in 1994. For every 20 PetroFina
shares held the Shareholder was granted one warrant at no cost. The warrants
were exercisable at a ratio of one warrant for one new share
F-33
<PAGE> 96
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(21) COMMON STOCK AND WARRANTS -- (CONTINUED)
during the period from May 20, 1997 through June 3, 1997 at a subscription price
of BEF 12,500 per share. In June 1997, 167,569 warrants were subscribed.
In June 1997, the company has issued for its personnel a debenture loan
with warrants.
The loan of BEF 375 million is composed of 75,000 bonds worth BEF 5,000
each, to which are attached 150,000 warrants. Each warrant grants the right to
subscribe to one PetroFina share at BEF 12,500 per share on the following dates:
June 30th 1998, 1999 and 2000. The maturity date of the debenture loan is set to
be the 30th of June 2000, to the extent that warrants have not been exercised
before.
(22) INVESTMENTS IN JOINT VENTURES
The Group consolidates certain jointly owned companies in accordance with
proportional consolidation principles, which under U.S. GAAP would be accounted
for under the equity method. The aggregate effect of applying the equity methods
of accounting would be a decrease in the Group's total assets of BEF 1.4
billion, in 1997 and an increase of BEF 1.9 billion and BEF 0.6 billion at
December 31, 1996 and 1995, respectively. This difference in accounting has no
effect on shareholders' equity or net income. These jointly owned companies
represent two industrial facilities, two smaller plants, and one marketing
company. All the above companies operate in either the Group's Downstream or
Chemical segments.
PetroFina's proportionate interests in the joint ventures, included in the
Group's consolidated financial statements, are as follows:
<TABLE>
<CAPTION>
1997 1996 1995
------- ------- -------
<S> <C> <C> <C>
DECEMBER 31,
Current assets.............................................. 4,306 4,992 4,919
Noncurrent assets........................................... 18,667 18,430 17,919
Current liabilities......................................... (7,650) (4,583) (3,861)
Noncurrent liabilities...................................... (12,393) (12,807) (14,369)
FOR THE YEAR ENDED DECEMBER 31,
Operating revenues.......................................... 13,036 11,987 10,726
Operating income............................................ 795 852 1,146
Net loss.................................................... 88 (68) (47)
Cash flows from:
-- Operating activities................................... 3,763 2,360 2,296
-- Financing activities................................... (1,305) 122 (1,552)
-- Investing activities................................... (3,625) (2,440) (778)
</TABLE>
(23) RELATED PARTY TRANSACTIONS
The Group accounts for certain companies following the equity method of
accounting. The Group's investment in these companies is included in Financial
assets. The equity affiliates are primarily engaged in exploration, production,
refining, distribution and marketing of crude oil, petroleum products and paints
in the United Kingdom, France, Holland, the United States and Angola.
Accounts and Notes Receivable in the Consolidated Balance Sheet include BEF
274.5 million, BEF 193 million and BEF 589 million at December 31, 1997, 1996
and 1995, respectively, of amounts due from equity affiliates. Accounts Payable
include BEF 1,074.9, BEF 2,555 million and BEF 2,986 million at December 31,
1997, 1996 and 1995, respectively, of amounts due to equity affiliates. Sales to
related parties
F-34
<PAGE> 97
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(23) RELATED PARTY TRANSACTIONS -- (CONTINUED)
were BEF 111.9 million for 1997, BEF 574 million for 1996 and BEF 517 million
for 1995. Sales price are determinated on arms-length principles.
(24) FINANCIAL RELATIONS WITH DIRECTORS AND MANAGERS
Salaries attributed to staff in charge of daily management (four executive
directors with permanent functions and eight general managers) as well as the
managers of the main subsidiaries amounted to BEF 230,214,704.
Bonus allocated to directors and to the eight general managers amounted to
BEF 103,850,000.
(25) OIL AND GAS RESERVES PER GEOGRAPHIC AREA (UNAUDITED)
The following table presents the Company's estimate of its proved oil and
gas reserves, for each foreign geographic area in which significant reserves are
located. The Company emphasizes that reserve estimates are inherently imprecise
and that estimates of new discoveries are more imprecise than those of producing
oil and gas properties. Accordingly, the estimates are expected to change as
future information becomes available.
The proved reserve estimates have been prepared by the Company's internal
petroleum reservoir engineers. Proved reserves are the estimated quantities of
crude oil, natural gas and natural gas liquids which geological and engineering
data demonstrate to be reasonably certain of recovery in future years from known
reservoirs under existing economic and operating conditions.
F-35
<PAGE> 98
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(25) OIL AND GAS RESERVES PER GEOGRAPHIC AREA (UNAUDITED) -- (CONTINUED)
CRUDE OIL (INCLUDING CONDENSATES AND NGL)
<TABLE>
<CAPTION>
EUROPE
AND REST OF NORTH EQUITY
THE WORLD AMERICA AFFILIATES TOTAL
----------- ------- ---------- ------
(in million barrels)
<S> <C> <C> <C> <C>
PROVED DEVELOPED AND UNDEVELOPED RESERVES
At December 31, 1994...................................... 500.86 31.86 26.33 559.05
Production of the year.................................. (46.72) (4.00) (0.25) (50.97)
Sales of minerals in place.............................. (2.15) (2.15)
Purchases of minerals in place.......................... 0.09 0.09
Extensions and discoveries.............................. 0.02 0.70 0.72
Revisions of previous estimates......................... 36.07 1.43 37.50
Improved recovery(1).................................... 24.59 6.73 31.32
------ ----- ----- ------
At December 31, 1995...................................... 514.82 34.66 26.08 575.56
------ ----- ----- ------
Production of the year.................................. (45.28) (3.95) (0.89) (50.12)
Sales of minerals in place.............................. (0.74) (0.74)
Purchases of minerals in place.......................... 0.68 1.13 1.81
Extensions and discoveries.............................. 0.54 43.30 43.84
Revisions of previous estimates......................... 14.14 2.91 0.56 17.61
Improved recovery....................................... 0.08 0.08
------ ----- ----- ------
At December 31, 1996...................................... 484.98 77.31 25.75 588.04
------ ----- ----- ------
Production of the year.................................. (48.18) (3.96) (1.72) (53.86)
Sales of minerals in place.............................. (3.84) (3.84)
Purchases of minerals in place.......................... 0.50 0.50
Extensions and discoveries.............................. 15.74 3.30 19.04
Revisions of previous estimates......................... 3.22 (0.68) 0.32 2.86
Improved recovery(2).................................... 54.49 54.49
------ ----- ----- ------
At December 31, 1997...................................... 510.25 72.63 24.35 607.23
------ ----- ----- ------
PROVED DEVELOPED RESERVES
At December 31, 1995...................................... 363.99 19.30 26.08 409.37
At December 31, 1996...................................... 342.59 21.42 25.75 389.76
At December 31, 1997...................................... 352.06 17.99 24.35 394.41
</TABLE>
- ---------------
(1) Amounts for improved recovery in 1995 are due to the optimization of well
locations related to the Ekofisk II redevelopment, horizontal drilling and
increased water injection in Norway.
(2) In 1997, the amounts for improved recovery included 35 million barrels for
the water injection program for Eldfisk and 19,5 million barrels for the
redevelopment of Congolese fields.
F-36
<PAGE> 99
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
(25) OIL AND GAS RESERVES PER GEOGRAPHIC AREA (UNAUDITED) -- (CONTINUED)
NATURAL GAS
<TABLE>
<CAPTION>
EUROPE
AND REST OF NORTH EQUITY
THE WORLD AMERICA AFFILIATES TOTAL
----------- ------- ---------- --------
(in billion of cubic feet)
<S> <C> <C> <C> <C>
PROVED DEVELOPED AND UNDEVELOPED RESERVES
At December 31, 1994.................................... 1,357.28 383.35 1,740.63
Production of the year................................ (150.11) (53.91) (204.02)
Sales of minerals in place............................ (12.97) (12.97)
Purchases of minerals in place........................ 0.10 0.10
Extensions and discoveries............................ 4.83 30.06 34.89
Revisions of previous estimates....................... 129.98 (9.73) 120.25
Improved recovery(1).................................. 85.80 0.29 86.09
-------- ------ --------
At December 31, 1995.................................... 1,427.78 337.19 1,764.97
-------- ------ --------
Production of the year.................................. (151.91) (58.77) (210.68)
Sales of minerals in place............................ (5.20) (5.20)
Purchases of minerals in place........................ 12.18 4.77 16.95
Extensions and discoveries............................ 10.92 134.62 145.54
Revisions of previous estimates....................... 50.24 (19.84) 30.40
Improved recovery
-------- ------ --------
At December 31, 1996.................................... 1,349.21 392.77 1,741.98
-------- ------ --------
Production of the year................................ (132.30) (76.58) (208.88)
Sales of minerals in place............................ (3.71) (3.71)
Purchases of minerals in place........................ 0.20 0.20
Extensions and discoveries............................ 6.42 88.47 94.89
Revisions of previous estimates....................... (77.90) (0.82) (78.72)
Improved recovery(2).................................. 42.56 42.56
-------- ------ --------
At December 31, 1997.................................... 1,187.99 400.33 1,588.32
-------- ------ --------
PROVED DEVELOPED RESERVES
At December 31, 1995.................................... 929.16 245.34 1,174.50
At December 31, 1996.................................... 801.24 249.61 1,050.85
At December 31, 1997.................................... 916.27 260.09 1,176.36
</TABLE>
- ---------------
(1) Amounts for improved recovery in 1995 are due to the optimization of well
locations related to the Ekofisk II redevelopment, horizontal drilling and
increased water injection in Norway.
(2) In 1997, the amounts for improved recovery included 42.4 billion cubic feet
for the water injection program for Eldfisk.
F-37
<PAGE> 100
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
RESULTS OF OPERATIONS FOR PRODUCING ACTIVITIES
The following table presents the results of operations for oil and gas
producing activities for the three years ended December 31, 1997.
<TABLE>
<CAPTION>
1997 1996 1995
------------------------- ------------------------- -------------------------
NORTH NORTH NORTH
EUROPE AMERICA TOTAL EUROPE AMERICA TOTAL EUROPE AMERICA TOTAL
------ ------- ------ ------ ------- ------ ------ ------- ------
(in BEF million)
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C>
Revenues:
Sales and other operating
revenues...................... 16,267 3,533 19,800 15,220 2,325 17,545 15,321 1,581 16,902
Transfers....................... 29,736 6,065 35,801 25,932 4,370 30,302 18,470 2,720 21,190
Operating Costs................... 13,070 2,253 15,323 11,764 1,671 13,435 11,014 1,684 12,698
Exploration Expenses.............. 2,203 2,151 4,354 1,775 1,255 3,030 2,681 1,505 4,186
Depreciation, Depletion and
Amortization.................... 8,289 3,452 11,741 6,605 2,310 8,915 6,899 1,770 8,669
------ ----- ------ ------ ----- ------ ------ ----- ------
Income Before Taxes............... 22,441 1,742 24,183 21,008 1,459 22,467 13,197 (658) 12,539
Income Tax Expenses............... 15,962 576 16,538 15,640 434 16,074 10,076 (235) 9,841
------ ----- ------ ------ ----- ------ ------ ----- ------
Results of Operations from
Producing Activities (Excluding
Interest Costs)................. 6,479 1,166 7,645 5,368 1,025 6,393 3,121 (423) 2,698
Group's Share of Equity Method
Investees' Results of Operations
for Producing Activities........ 690 86 776 892 -- 892 484 48 532
------ ----- ------ ------ ----- ------ ------ ----- ------
TOTAL: Results of Operations from
Producing Activities
(Excluding Interest
Costs)..................... 7,169 1,252 8,421 6,260 1,025 7,285 3,605 (375) 3,230
</TABLE>
F-38
<PAGE> 101
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
COSTS INCURRED ON OIL & GAS PROPERTIES
A summary of costs incurred in oil and gas property acquisition,
exploration and development activities, (both capitalized and charged to
expense) for the periods noted follows:
<TABLE>
<CAPTION>
EUROPE
AND REST OF NORTH
THE WORLD AMERICA TOTAL
----------- ------- ------
(in BEF million)
<S> <C> <C> <C>
1997
Acquisition of unproved properties.......................... 98 473 571
Acquisition of proved properties............................ 6 -- 6
Exploration costs........................................... 2,819 1,910 4,729
Development costs........................................... 12,708 5,716 18,424
------ ----- ------
TOTAL............................................. 15,631 8,099 23,730
------ ----- ------
1996
Acquisition of unproved properties.......................... -- 256 256
Acquisition of proved properties............................ -- 128 128
Exploration costs........................................... 2,082 1,781 3,863
Development costs........................................... 11,357 3,035 14,392
------ ----- ------
TOTAL............................................. 13,439 5,200 18,639
------ ----- ------
1995
Acquisition of unproved properties.......................... -- 157 157
Acquisition of proved properties............................ -- 33 33
Exploration costs........................................... 2,189 1,464 3,653
Development costs........................................... 8,187 1,110 9,297
------ ----- ------
TOTAL............................................. 10,376 2,764 13,140
------ ----- ------
</TABLE>
SUPPLEMENT OIL & GAS DATA CAPITALIZED COSTS
<TABLE>
<CAPTION>
1997 1996 1995
----------------------------- ---------------------------- ---------------------------
NORTH NORTH NORTH
EUROPE AMERICA TOTAL EUROPE AMERICA TOTAL EUROPE AMERICA TOTAL
-------- ------- -------- ------- ------- -------- ------- ------- -------
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C>
Proved Oil and Gas Properties....... 126,449 41,971 168,420 114,791 32,934 147,725 104,326 28,030 132,356
Unproved Oil and Gas Properties..... 12,388 5,535 17,923 11,155 5,645 16,800 10,210 4,198 14,408
Support facilities and other........ 22,493 8,054 30,547 14,097 5,152 19,249 6,187 2,919 9,106
-------- ------- -------- ------- ------- -------- ------- ------- -------
161,330 55,560 216,890 140,043 43,731 183,774 120,723 35,147 155,870
-------- ------- -------- ------- ------- -------- ------- ------- -------
Less Accumulated Depreciation,
Depletion, Amortization and
Impairment........................ (101,243) (31,096) (132,339) (87,865) (25,061) (112,926) (77,087) (19,457) (96,544)
-------- ------- -------- ------- ------- -------- ------- ------- -------
60,087 24,464 84,551 52,178 18,670 70,848 43,636 15,690 59,326
-------- ------- -------- ------- ------- -------- ------- ------- -------
Share of Net Capitalized Costs of
Equity Affiliates................. 1,087 863 843
</TABLE>
F-39
<PAGE> 102
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS AND CHANGES
THEREIN RELATING TO PROVED OIL AND GAS RESERVES (UNAUDITED)
The following table, which presents a standardized measure of discounted
future net cash flows and changes therein relating to proved oil and gas
reserves, is presented pursuant to United States Statement of Financial
Accounting Standards No. 69. In computing this data, assumptions other than
those required by the Financial Accounting Standards Board could produce
different results. Accordingly, the data should not be considered as
representative of the fair market value of the Company's proved oil and gas
reserves.
Future cash inflows were computed by applying year end realized prices for
oil and gas production to estimated year end quantities of proved reserves.
Future price changes were considered only to the extent provided by contractual
agreements in existence at the date of computation. Future development and
production costs are computed by estimating the expenditures to be incurred in
developing and producing the proved oil and gas reserves, at the end of the
year, based on year end costs. Future income tax expenses were computed by
applying the year end statutory tax rate adjusted for tax credits, less the tax
basis of the properties involved. The impact of changes in the year end taxes on
future pre-tax net cash flows relating to proved oil and gas reserves is
considered to the extent that these changes are legislated. The standardized
measure of discounted future cash flows represents the present value of
estimated future net cash flows using a discount rate of 10%.
<TABLE>
<CAPTION>
1997 1996 1995
----------------------------- ----------------------------- -----------------------------
NORTH NORTH NORTH
EUROPE AMERICA TOTAL EUROPE AMERICA TOTAL EUROPE AMERICA TOTAL
-------- ------- -------- -------- ------- -------- -------- ------- --------
(in BEF million)
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C>
Future cash
inflows............ 418,548 67,203 485,751 484,770 94,541 579,311 393,173 37,069 430,242
Future production and
development
costs.............. (188,037) (28,497) (216,534) (182,152) (27,984) (210,136) (183,804) (14,391) (198,195)
Future income tax
expenses........... (138,065) (8,236) (146,301) (206,151) (18,426) (224,577) (135,424) (3,293) (138,717)
FUTURE NET CASH
FLOWS.............. 92,446 30,470 122,916 96,467 48,131 144,598 73,945 19,385 93,330
-------- ------- -------- -------- ------- -------- -------- ------- --------
10% annual discount
for estimated
timing of cash
flows.............. (33,610) (11,669) (45,279) (35,693) (20,379) (56,072) (31,698) (7,593) (39,291)
-------- ------- -------- -------- ------- -------- -------- ------- --------
Standardized measure
of discounted
future net cash
flows.............. 58,836 18,801 77,637 60,774 27,752 88,526 42,247 11,792 54,039
-------- ------- -------- -------- ------- -------- -------- ------- --------
Enterprise's share of
equity method
investee's
standardized
measure of
discounted future
net cash flows..... 1,447 0 1,447 1,956 0 1,956 1,548 0 1,548
</TABLE>
F-40
<PAGE> 103
PETROFINA
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
CHANGE IN THE STANDARDIZED MEASURE
STANDARDIZED MEASURE
<TABLE>
<CAPTION>
1997 1996 1995
-------- -------- --------
(in BEF million)
<S> <C> <C> <C>
STANDARDIZED MEASURE (beginning of year).................... 88,526 54,039 43,446
Change in sales prices related to future production......... (60,519) 53,243 27,710
Change in estimated future lifting and development costs.... (10,557) (2,453) 3,071
Sales and transfers of oil and gas produced during the
period, net of production costs........................... (41,092) (35,743) (26,006)
Extensions, discoveries and improved recovery, less related
costs..................................................... 17,625 17,795 7,657
Revisions in previously estimated quantities................ (11,555) 14,310 12,520
Previously estimated development costs incurred during the
period.................................................... 16,065 14,860 9,538
Sales of minerals in place.................................. (963) (923) (1,331)
Purchases of minerals in place.............................. 127 2,129 35
Accretion of discount....................................... 22,468 12,506 9,038
Net change in income taxes.................................. 50,075 (47,554) (27,683)
Exchange effect............................................. 7,437 6,317 (3,956)
------- ------- -------
STANDARDIZED MEASURE (END OF YEAR).......................... 77,637 88,526 54,039
</TABLE>
F-41
<PAGE> 104
SCHEDULE II
PETROFINA
CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
--------------------------------------------------------
BEGINNING CHARGED TO COSTS BALANCE
OF PERIOD AND EXPENSES DEDUCTIONS(1) AT END OF
--------- ---------------- ------------- ---------
(in BEF million)
<S> <C> <C> <C> <C>
December 31, 1995
-- allowance for doubtful receivables........ 2,527 389 (416) 2,500
-- inventory valuation reserve............... 1,173 (278) (60) 835
December 31, 1996
-- allowance for doubtful receivables........ 2,500 537 (220) 2,817
-- inventory valuation reserve............... 835 (299) 4 540
December 31, 1997
-- allowance for doubtful receivables........ 2,817 207 (239) 2,785
-- inventory valuation reserve............... 540 351 (368) 523
</TABLE>
- ---------------
(1) Utilization and monetary adjustments
F-42
