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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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FORM 20-F
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(MARK ONE)
[ ] REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR (g)
OF THE SECURITIES EXCHANGE ACT OF 1934
OR
[ ] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
OR
[X] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
FOR THE TRANSITION PERIOD FROM JULY 1, 1997 TO DECEMBER 31, 1997
COMMISSION FILE NUMBER 1-14634
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SANTA FE INTERNATIONAL CORPORATION
(Exact name of Registrant as specified in its charter)
CAYMAN ISLANDS
(Jurisdiction of incorporation or organization)
TWO LINCOLN CENTRE, SUITE 1100
5420 LBJ FREEWAY
DALLAS, TEXAS 75240-2648
(Address of principal executive offices)
Securities registered or to be registered pursuant to Section 12(b) of the Act.
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TITLE OF EACH NAME OF EACH EXCHANGE
CLASS ON WHICH REGISTERED
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Ordinary Shares, par value $0.01 per share New York Stock Exchange
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Securities registered or to be registered pursuant to Section 12(g) of the Act.
NONE
(Title of Class)
Securities for which there is a reporting obligation pursuant to Section 15(d)
of the Act.
NONE
(Title of Class)
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: 114,746,550 Ordinary Shares, par value $0.01 per share
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 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]
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TABLE OF CONTENTS
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PAGE
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PART I.................................................................. 1
Item 1. Description of Business..................................... 1
Item 2. Description of Property..................................... 18
Item 3. Legal Proceedings........................................... 19
Item 4. Control of Registrant....................................... 19
Item 5. Nature of Trading Market.................................... 20
Item 6. Exchange Controls and Other Limitations Affecting Security
Holders................................................... 20
Item 7. Taxation.................................................... 20
Item 8. Selected Consolidated Financial Data........................ 21
Item 9. Management's Discussion and Analysis of Financial Condition
and Results of Operations................................. 22
Item 9a. Quantitative and Qualitative Disclosures about Market
Risk...................................................... 33
Item 10. Directors and Officers of Registrant........................ 33
Item 11. Compensation of Directors and Officers...................... 35
Item 12. Options to Purchase Securities from Registrant or
Subsidiaries.............................................. 39
Item 13. Interest of Management in Certain Transactions.............. 40
PART II................................................................. 44
Item 14. Description of Securities to Be Registered.................. 44
PART III................................................................ 44
Item 15. Defaults upon Senior Securities............................. 44
Item 16. Changes in Securities and Changes in Security for Registered
Securities................................................ 44
PART IV................................................................. 44
Item 17. Financial Statements........................................ 44
Item 18. Financial Statements........................................ 44
Item 19. Financial Statements and Exhibits........................... 44
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FORWARD-LOOKING STATEMENTS
This Transition Report on Form 20-F contains certain forward-looking
statements, including without limitation statements containing the words
"believes," "anticipates," "expects" and words of similar import. Such
forward-looking statements involve known and unknown risks, uncertainties and
other factors which may cause the actual results, financial condition,
performance or achievements of the Company (defined below), or industry results,
to be materially different from any future results, performance or achievements
expressed or implied by such forward-looking statements. Such factors include,
among others, the following: adverse changes in contract drilling industry
conditions, oil and gas prices, competition from other drilling contractors,
increase in industry fleet capacity, the impact of present or future
environmental legislation and compliance with environmental laws, the ongoing
need for capital improvements, refurbishing and fabrication costs for drilling
rigs, the availability and replacement costs for rig related equipment, spare
parts and supplies, financing costs, changes in operating expenses, attraction
and retention of skilled employees, uncertainties arising out of the Company's
operations outside the United States, adverse changes in applicable tax laws,
adverse changes in governmental rules and fiscal policies, civil unrest, acts of
God, acts of war, and other factors referenced in this Transition Report on Form
20-F. Certain of these factors are discussed in more detail elsewhere in this
Transition Report on Form 20-F, including without limitation "Item
1. Description of Business" and "Item 9. Management's Discussion and Analysis of
Financial Condition and Results of Operations." Given these uncertainties,
readers are cautioned not to place undue reliance on such forward-looking
statements. The Company disclaims any obligation to update any such
forward-looking statements to reflect future events or developments.
PART I
ITEM 1. DESCRIPTION OF BUSINESS.
GENERAL
Santa Fe International Corporation (herein referred to individually and,
where the context so requires, collectively with its subsidiaries and
predecessors as "Santa Fe" or the "Company") is a leading international offshore
and land contract driller that was incorporated in its current form under the
laws of the Cayman Islands in 1990. As of February 28, 1998, the Company owns
and operates a high quality, technologically advanced fleet of 26 marine
drilling rigs and 29 land drilling rigs. Santa Fe is also a leading provider of
drilling related services to the petroleum industry worldwide, including third
party rig operations, incentive drilling and drilling engineering and project
management services. The Company is currently operating in 16 countries
throughout the world. The Company's predecessor began U.S. land drilling
operations in 1947, commenced international land operations in 1948, expanded
into offshore platform drilling in 1956 and initiated mobile offshore rig
operations in 1964.
At the core of Santa Fe's drilling rig fleet is its fleet of heavy duty
harsh environment jackup rigs (four of the 14 currently in service in the
industry), which are capable of operating in water depths of up to 350-400 feet.
The Company has two additional heavy duty harsh environment rigs under
construction including the Galaxy II, which is contracted to be placed in
service in the fourth quarter of 1998. Construction of the Galaxy III was
initiated during the reporting period, and the rig is contracted to be placed in
service in the fourth quarter of 1999. Further, Santa Fe has three deep water
semisubmersible rigs which are capable of operating in water depths of up to
2,000-2,400 feet; eight cantilever jackup rigs which are capable of operating in
water depths of up to 300-350 feet; nine jackup rigs which are capable of
operating in water depths of up to 200-250 feet, seven of which are cantilevered
and two of which are specially designed to operate in shallow water; one lake
barge rig; one platform rig; and 29 land rigs, all of which are specially
equipped to operate in remote areas. See Note 11 of the Notes to Consolidated
Financial Statements for certain financial data pertaining to the Company's
business in various regions.
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INDUSTRY CONDITIONS
Offshore contract drilling industry conditions, and resulting offshore
drilling rig utilization and dayrates, have improved substantially since the
beginning of 1995, while land rig dayrates during that period have been
relatively stable in the markets in which the Company operates. From the
mid-1980s through the early 1990s, demand for offshore drilling rigs was
declining or stagnant, and the industry fleet of offshore rigs was reduced,
primarily by attrition. In recent years the industry has emphasized the
upgrading and refurbishment of existing rigs, in addition to construction of new
rigs.
Several trends have increased the demand for drilling rigs over the past
few years. They include technological advancements, oil company downsizing,
establishment of government sponsored exploration, development and production
sharing programs, and growing deep water exploration. Rising worldwide energy
demand over the past several years has improved fundamentals in the oil and
natural gas markets. Consequently, oil companies have begun to spend more to
find and develop new reserves. However, drilling budgets may be impacted by
fluctuations in oil and natural gas prices. Such prices tend to fluctuate in
response to relatively minor changes in supply and demand which is influenced by
several factors, including worldwide consumption, political events, climatic
changes and related factors. Drilling expenditure budget fluctuations have a
direct impact upon the demand and rates for drilling rigs.
Technological advances such as extended reach drilling, multi-lateral
drilling techniques and new offshore development and production applications
have reduced the costs of developing oil and gas fields. As a result, previously
uneconomic discoveries have become viable and the industry has placed increasing
emphasis on exploiting existing resources using new applications. The
development of three and four dimensional seismic surveys has reduced
exploration risks, thus placing increased emphasis on selective exploratory
drilling. Government sponsored exploration, development and production sharing
programs are growing in number and many of those programs require oil companies
to commence drilling within specified time periods.
BUSINESS STRATEGY
The Company's business strategy is to provide premium quality,
cost-effective services to its customers in order to maximize the utilization of
its rig fleet at attractive dayrates, with the goal of enhancing shareholder
value. The Company's understanding of its customers' future needs guides
strategic decisions regarding investment in equipment, selection of geographic
markets and development of Company skills. The following are the principal
components of the Company's business strategy:
Modern Rig Fleet
The Company continually invests in its drilling fleet through the
acquisition and construction of new rigs and the upgrading, modernization and
enhancement of existing rigs to increase drilling productivity and prolong rig
life. Santa Fe rigorously evaluates each of its investments based on expected
long term return on capital and profitability. For example, between 1988 and
1992 the Company made significant counter-cyclical purchases of five new jackup
rigs, including the Company's entire fleet of four heavy duty harsh environment
jackup rigs and a 300-foot cantilever jackup rig. In 1993, the Company purchased
and extensively upgraded an additional 300-foot cantilever jackup rig. The
Company has two additional heavy duty harsh environment rigs under construction
including the Galaxy II, which is contracted to be placed in service in the
fourth quarter 1998. Construction of the Galaxy III was initiated during the
reporting period, and the rig is contracted to be placed in service in the
fourth quarter of 1999. Beginning in 1996, the Company commenced an expansion of
its land rig fleet through the addition of five specialized, highly mobile rigs
and two heavy duty 3,000 horsepower rigs equipped with top drives. The Company
has continued the expansion of its land rig fleet with the addition of one light
duty rig in Egypt and the acquisition and assembly of two medium duty and two
heavy duty land rigs scheduled to begin work in Venezuela in 1998. The Company's
rig fleet upgrade, modernization and enhancement program has included
installation of top drive systems, improvements in mud processing and liquid
storage capacity, jackup leg extensions, cantilever and skid-off capability. See
"Item 9. Management's Discussion and Analysis of Financial Condition and Results
of Operations -- Liquidity and Capital Resources."
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International Focus
The Company operates primarily outside the U.S., with its rigs currently
deployed in seven major market areas around the world. The Company first
operated in each of these markets more than 25 years ago. Santa Fe believes the
operational expertise, international workforce and business relationships it has
established through its longstanding presence in its major international markets
provide it with a competitive advantage in securing work on attractive terms.
The Company favors markets where there is an opportunity to establish a
significant presence and benefit from efficiencies associated with market
concentration, but also seeks selected opportunities in niche and emerging
markets.
The Company believes that international markets generally require more
specialized equipment and value added technical expertise than the U.S. market,
providing Santa Fe with greater opportunities to secure attractive contracts.
Furthermore, the Company believes that international markets for drilling
services are less influenced by volatility in the prices of oil and natural gas
than the U.S. market, thus increasing the relative stability of its operations.
The Company's international focus enables it to minimize the level of worldwide
taxation on its revenues, income and assets through various tax-efficient
business structures.
The Company seeks international contracts payable in local currency in
amounts equal to the Company's estimated operating costs payable in local
currency and in dollars for the balance of the contract. Accordingly, the
Company has not historically entered into financial hedging arrangements to
manage risks relating to fluctuations in currency exchange rates. However, the
Company may enter into such contracts in the future in the event that the
Company assumes significant foreign currency risks.
High Quality Multinational Workforce
The Company distinguishes itself with its high quality, well-trained and
cost-effective rig crew and supervisory workforce. The breadth and depth of the
Company's workforce enable it to efficiently staff its own rigs and profitably
provide labor and management services for the operation and maintenance of third
party rigs. The Company's rig crew and supervisory personnel are drawn largely
from the countries in which the Company has longstanding operations. The quality
of Santa Fe's workforce and training program is reflected in its safety
performance record, which has consistently exceeded the industry norm over the
past decade, as compiled by the International Association of Drilling
Contractors.
Specialized Drilling Services
The Company provides drilling services requiring special expertise and
technical innovation, such as high pressure, high temperature drilling and
jackup rig skid-off drilling. The Company's ability to deliver such services is
enhanced by the operational expertise and efficiencies it has developed from its
long term presence in selected markets. By taking advantage of innovative
contracting opportunities, including incentive contracts, the Company enhances
the profitability of its drilling services.
BUSINESS CONSIDERATIONS AND RISK FACTORS
Contract Drilling Industry Volatility and Competition
The contract drilling industry is and historically has been highly
volatile, competitive and cyclical, with periods of high demand and rig
utilization with resulting high rig dayrates followed by periods of low demand,
excess rig supply and depressed rig dayrates. The contract drilling business is
influenced by many factors beyond the control of the Company, including the
worldwide demand for, and the current and anticipated prices of, oil and natural
gas, the level of exploration and production drilling expenditures by oil and
gas companies, the ability of the Organization of Petroleum Exporting Countries
("OPEC") to influence production levels and pricing, the level of production of
non-OPEC countries, the policies of various governments regarding exploration
and development of their oil and natural gas resources and the availability of
drilling rigs.
Oil and natural gas prices fluctuate in response to relatively minor
changes in the supply of and demand for oil and natural gas, market uncertainty
and a variety of additional factors. It is impossible to predict future
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oil and natural gas price movements with any certainty. Such fluctuations can
impact drilling budgets. Drilling expenditure budget fluctuations have a direct
impact upon the demand and rates for drilling rigs.
Drilling rig dayrates and utilization generally were depressed for over a
decade beginning in the early 1980s, due to an oversupply of drilling rigs, low
oil and natural gas prices and a corresponding reduction in exploration and
development activities by the world's major oil producers. Offshore contract
drilling industry conditions, and resulting offshore drilling rig utilization
and dayrates, have improved substantially over the last two to three years. Land
rig dayrates during that period have improved in the markets in which the
Company operates, although not as significantly as for the offshore drilling
industry. There can be no assurance as to the duration of these conditions.
In the contract drilling industry, contracts generally are awarded on a
competitive bid basis and, although a customer selecting a rig may consider
factors such as a contractor's safety record, crew competence, quality of
service, and capabilities and condition of equipment, price often is the primary
determining factor in the selection of a drilling contractor. The Company
believes that competition for drilling contracts will continue to be strong for
the foreseeable future.
Recent improvements in the offshore contract drilling industry as a whole
have led to increased rig construction and enhancement programs by the Company
and its competitors. If present trends continue for an extended period, these
improvements may attract new competitors into the market. Rig construction,
movement or reactivation, or a decrease in drilling activity in any major
market, could depress rig dayrates and could adversely affect utilization of the
Company's rigs.
The Company has recently experienced increased pressure on operating costs
in the form of increased labor costs, resulting from competition for skilled
employees, and significantly increased prices and delivery delays for vendor
equipment and materials. It is likely that these factors could continue to
impact results of operations for the foreseeable future.
Operational Risks, Insurance and Indemnification
Oil and natural gas drilling operations are subject to many risks,
including blowouts, cratering, oil or natural gas well fires, explosions, oil
spills and other disasters, each of which could result in substantial losses to
the Company due to injury or loss of life and damage to or destruction of rigs,
oil and natural gas wells, reservoirs, production facilities or other
properties. In addition, the Company's offshore and marine equipment is subject
to hazards peculiar to marine operations, such as sinking, capsizing, grounding,
collision and damage from heavy weather or hurricanes. Loss of or serious damage
to certain of the Company's equipment, even if adequately covered by insurance,
might materially reduce the Company's revenues and operating profit for an
extended period of time.
The Company evaluates its exposure to certain risks when participating in
any project and, to the extent permitted by market conditions, contracts with
its customers or joint venture partners to provide the Company with
indemnification or other protection against certain risks, including those not
generally covered by insurance and losses in excess of applicable insurance
limits. There can be no assurance that the Company can obtain effective
indemnification in all of its contracts, that the level of indemnification that
can be obtained will be meaningful, that such indemnification agreements will be
enforceable or that the customer will be financially able to comply with its
indemnity obligations. See "-- Risks, Insurance and Indemnification" for a
discussion of the Company's insurance coverage.
Governmental Regulation
Many aspects of the Company's operations are affected periodically by
political developments and by both domestic and foreign governmental
regulations, including those relating to the construction, equipment and
operation of drilling rigs, drilling practices and methods and levels of
taxation, as well as additional hazards and uncertainties, such as the risk of
expropriation, foreign exchange restrictions, fluctuations in currency exchange
rates, foreign and domestic monetary, economic and trade policies, and
environmental regulation. The energy service industry is dependent on demand for
its services from the oil and gas industry
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and, accordingly, is affected by changing taxes, price controls and other laws
relating to the energy business generally. Governments may, from time to time,
suspend or curtail drilling operations or leasing activities when such
operations are considered to be detrimental to the environment or to jeopardize
public safety. Many jurisdictions have at various times imposed limitations on
the production of oil and natural gas by restricting the rate of flow for oil
and natural gas wells below their natural capacity. There can be no assurance
that present or future regulation will not adversely affect the operations of
the Company.
As of February 28, 1998, all of the Company's rigs were engaged in
operations or activities outside the United States and its territorial waters,
with the exception of one semisubmersible rig operating in the U.S. Gulf of
Mexico. With respect to the Company's operations in the U.S. Gulf of Mexico or
elsewhere in the U.S. Outer Continental Shelf, state or territorial waters, the
U.S. Oil Pollution Act of 1990 ("OPA '90") and similar legislation or
regulations enacted in Texas, Louisiana and other coastal states address oil
spill prevention and control and impose a variety of obligations on the Company
related to the prevention of oil spills and liability for damages resulting from
such spills. OPA '90 imposes strict and, with limited exceptions, joint and
several liability upon each responsible party for oil removal costs and a
variety of public and private damages, including civil and criminal penalties,
and also imposes ongoing financial responsibility requirements on a responsible
party.
The Company's worldwide operations are also subject to a variety of laws
and regulations designed to improve safety in the businesses in which the
Company operates. International conventions, including Safety of Life at Sea
(SOLAS), the Convention For Prevention of Oil Pollution by Ships at Sea (MARPOL)
and the Code for Construction of Mobile Offshore Drilling Units (MODU CODE),
generally are applicable to the Company's offshore operations. The Company's
operations in the U.K. sector of the North Sea are also subject to strict
regulatory requirements, including the Mineral Workings Act (MWA) 1971 and the
Health and Safety at Work Act (HASAWA) 1974. Historically, the Company has made
significant capital expenditures and incurred additional expenses to ensure that
its marine rigs comply with applicable local and international health and safety
regulations. Future efforts by the Company to comply with these regulations and
standards may increase the Company's costs and may affect the demand for the
Company's services by influencing energy prices or limiting the areas in which
drilling may be performed.
Taxation Risks
As a Cayman Islands company primarily doing business outside the U.S., the
Company is taxed at rates substantially lower than if it were engaged in a U.S.
trade or business. Although almost all of its operations are outside the U.S.,
the Company has an office in Texas from which a number of senior management
personnel generally oversee, supervise and control the policies of the Company.
The Company reports only income attributable to the functions performed in the
U.S. as income effectively connected with a U.S. business. If income earned from
its worldwide operations were deemed by the Internal Revenue Service to be
effectively connected with a U.S. business, the Company could be subjected to
U.S. income tax on such effectively connected income, and its operating results
could be materially adversely affected. The Company's international focus
enables it to reduce the level of worldwide taxation on its revenues, income and
assets through various tax-efficient business structures. The Company could
suffer substantial additional tax expense in the event any of its existing
business structures were successfully challenged or in the event of an adverse
change in the treaties, laws, rules or regulations (or the interpretation
thereof) upon which the Company has relied in relation to its business
strategies and structures. See "Item 7. Taxation," "Item 9. Management's
Discussion and Analysis of Financial Condition and Results of Operations" and
Note 5 of the Notes to Consolidated Financial Statements. In addition, demand
for services in the drilling industry is dependent on the oil and gas
exploration industry and accordingly is affected by changes in tax and other
laws relating to the energy business generally.
Environmental and Regulatory Risks
The Company's worldwide operations are subject to numerous international,
U.S., state and local environmental laws and regulations that relate directly or
indirectly to its operations, including certain regulations controlling the
discharge of materials into the environment, requiring removal and clean-up
under
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certain circumstances, or otherwise relating to the protection of the
environment. For example, the Company may be liable for damages and costs
incurred in connection with oil spills for which it is held responsible. Laws
and regulations protecting the environment have become increasingly stringent in
recent years and may in certain circumstances impose "strict liability" and
render a company liable for environmental damage without regard to negligence or
fault on the part of such company. Such laws and regulations may expose the
Company to liability for the conduct of or conditions caused by others, or for
acts of the Company that were in compliance with all applicable laws at the time
such acts were performed. The Company believes its operations are in compliance
in all material respects with all such laws and regulations. The application of
these requirements or the adoption of new requirements could have a material
adverse effect on the Company. See "-- Governmental Regulation" for a discussion
of the Company's regulatory operating requirements.
Governments may, from time to time, suspend or curtail drilling operations
or leasing activities when such operations are considered to be detrimental to
the environment or to jeopardize public safety. Many jurisdictions have at
various times imposed limitations on the production of oil and natural gas by
restricting the rate of flow for oil and natural gas wells below their natural
capacity. There can be no assurance that present or future regulation will not
adversely affect the operations of the Company.
The Company may be required to make significant capital expenditures in the
future to comply with laws and regulations that become applicable to the Company
and such compliance could materially adversely affect the earnings or
competitive position of the Company. It is possible that such regulations may in
the future add significantly to the cost of operating drilling equipment or may
significantly limit drilling activity. See "-- Governmental Regulation" and
"Item 3. Legal Proceedings."
Contract Termination and Performance Risks
The Company's contracts with its customers often are cancelable upon
specified notice at the option of the customer, and some, but not all, contracts
provide for the customer to pay a specified early termination payment in the
event of such cancellation that may not be sufficient to fully compensate the
Company for the loss of the contract. Early termination of a contract may result
in a rig being idle for an extended period of time. Contracts customarily
provide for either automatic termination or termination at the option of the
customer in the event of total loss of the drilling rig or if drilling
operations are suspended for extended periods of time by reason of force majeure
or excessive rig downtime for repairs. In periods of rapid market downturn, the
Company's customers may not honor the terms of existing contracts and may
terminate contracts or require the Company to renegotiate contract rates and
terms to conform with depressed market conditions, reducing the Company's
revenues.
The Company selectively engages in drilling services pursuant to turnkey
drilling contracts under which the Company agrees to drill a well for a customer
to a specified depth, and to provide the associated services and well
consumables for a fixed price. Generally, the Company is not entitled to payment
unless the well is successfully drilled to the specified depth, and
profitability of the contract depends upon an ability to keep expenses within
the estimates used by the Company in determining the contract price. Drilling a
well under a turnkey contract therefore typically requires a cash commitment by
the Company in excess of that required under a conventional dayrate contract and
exposes the Company to risks of potential financial losses. These losses could
be substantially greater than those that would ordinarily exist under a
conventional dayrate contract and may include losses resulting from delays in
drilling progress or loss of a well or portion thereof. Although the Company
carefully evaluates the associated risks, the financial results of a turnkey
contract depend upon the performance of the drilling unit, drilling conditions
and other factors, some of which are beyond the control of the Company.
Additionally, the Company undertakes certain risks when entering into footage
and other incentive contracts, alliances and drilling project management
contracts where a portion of the remuneration is dependent upon achieving
specified performance goals. A failure to meet the performance criteria may
result in lower revenue to the Company and, in certain circumstances, also may
cause the Company to incur a monetary penalty, often in the form of reduced or
suspended remuneration. See "-- Contracts."
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Dependence on Workforce
The Company's high quality, well-trained and cost-effective rig crew and
supervisory workforce contributes significantly to its ability to deliver
premium quality services. If the Company were unable to retain its current
workforce or to hire comparable personnel, it could have a material adverse
effect on the success of the Company. The Company does not maintain key-person
insurance for any of its senior management personnel.
Uncertainties and Risks of Non-U.S. Operations
Operations outside the U.S. account for substantially all of the Company's
consolidated revenues. The Company's non-U.S. operations are subject to certain
political, economic and other uncertainties not generally encountered in the
U.S., including hazards incident to war and civil disturbances (or other hazards
that may limit or disrupt markets) and the general hazards associated with the
assertion of national sovereignty over certain areas in which operations are
conducted. These risks are mitigated by the Company's ability to relocate its
rigs. The Company's operations outside the United States are also subject to
foreign customs and business practices, to changes in political conditions, such
as confiscatory taxation, unreasonable regulation, unrealistic pricing or
royalty terms, export sales restrictions, embargoes and expropriation or
nationalization with or without compensation, to the additional risks of
fluctuating currency values and hard currency shortages, to the possibility of
realizing economic currency exchange losses when transactions are completed in
currencies other than dollars and to the Company's ability to freely repatriate
its earnings under existing exchange control laws. Additionally, export
restrictions or trade sanctions imposed by the U.S. Government under the Export
Administration Act, the Trading With the Enemies Act or similar legislation or
regulation may impede the Company's ability, or the ability of its customers, to
operate or continue to operate in certain countries. No prediction can be made
as to what governmental regulations may be enacted in the future that could
adversely affect the international drilling industry.
Control by Holdings and Potential Conflicts of Interest
As of February 28, 1998, SFIC Holdings (Cayman), Inc. ("Holdings"), a
wholly owned subsidiary of Kuwait Petroleum Corporation ("KPC"), beneficially
owned approximately 64.9% of the outstanding ordinary shares, par value $0.01
per share, of the Company ("Ordinary Shares"). KPC is wholly owned by the
Government of Kuwait. Accordingly, KPC through Holdings is able to elect the
Board of Directors of the Company and effectively control the outcome of the
vote on certain matters submitted to a vote of the Company's shareholders. The
Company, Holdings and KPC have entered into agreements with respect to the
approval by Holdings of certain future corporate actions by the Company, the
management and allocation of certain liabilities relating to former non-drilling
activities of the Company, registration rights for the Ordinary Shares owned by
Holdings, and various other matters. See "Item 10. Directors and Officers of the
Registrant" and "Item 13. Interest of Management in Certain Transactions."
DRILLING RIG FLEET AND DRILLING RELATED SERVICES
Marine Rigs
A marine rig consists of a suite of drilling equipment mounted on a hull or
offshore platform. The drilling equipment generally is comprised of a derrick or
mast, hoisting equipment, a rotary system, well control equipment, systems for
storing, treating and pumping drilling fluids, and a power plant. The
specifications of this drilling equipment will determine the drilling
capabilities of the rig. Offshore rigs and inland barges also generally include
living quarters, cranes, heliports, and storage areas for drill pipe and drill
collars and other materials. The design of the rig and its hull determines the
marine areas in which it can operate. The Company's marine fleet consists of 21
jackup rigs, three semisubmersible rigs, one inland barge rig and one platform
rig. For financial reporting purposes, the Company's inland barge rig and
platform rig are combined under the heading "Other Marine Rigs." The Company's
marine rigs that are documented as vessels are registered outside the U.S.
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Jackup Rigs. The Company classifies its jackup rigs in three categories:
heavy duty harsh environment rigs, 300-350 foot cantilever rigs, and 200-250
foot rigs. A jackup is a mobile rig that jacks down its legs to stand on the sea
floor with its hull elevated above the water surface during drilling operations.
For transportation between locations, the legs are raised and the hull is
floated. The legs are raised and lowered by multiple jacking units attached to
the legs. The water depth limit for each rig is a function of several factors,
including leg length, sea floor conditions and the anticipated wind, wave and
current severity. Jackup rigs can be used to drill exploration wells or to drill
multiple production wells at the same location. Several features are important
for this latter capability. A cantilever, on which is mounted the derrick, drill
floor and substructure, enables the rig to drill alongside and over an adjacent
platform or subsea template and to drill multiple wells at the same location
without repositioning the rig. Nineteen of the Company's 21 jackup rigs are
cantilevered and four of them also have skid-off capability which enables the
drilling system to be skidded onto a production platform for development
drilling while the rig serves in a tender-assist mode. All of the Company's
jackup rigs are equipped with top-drives. A top-drive enables the rig to drill
long, highly deviated wells both more efficiently and more safely than
conventional rotary equipment.
The Company owns one of the world's largest fleet of heavy duty harsh
environment jackup rigs (four of the 14 currently in service in the industry).
One of these rigs, the Galaxy I, is a Universe class rig design capable of
operating in water depths of up to 400 feet and is currently operating
year-round in the harsh environment of the central North Sea in water depths of
up to 360 feet. The Company is currently constructing two additional rigs of
this class, the Galaxy II and the Galaxy III. The Galaxy II is scheduled to be
placed in service during the fourth quarter of 1998 and is contracted to
initially operate offshore Nova Scotia for a five year term. The Galaxy III is
expected to be placed in service during the fourth quarter of 1999 and is
contracted to work in the U.K. sector of the North Sea for an initial term of
three years. The Company's three other heavy duty harsh environment jackup rigs,
the Monarch, Monitor and Magellan, are Monarch class rig designs capable of
operating in water depths of up to 350 feet and are currently operating
year-round in the central North Sea in water depths of up to 310 feet.
Two of the Company's 300-350 foot cantilever jackup rigs are capable of
operating in water depths up to 350 feet and six are capable of operating in
water depths of up to 300 feet. Seven of the Company's 200-250 foot jackup rigs
are capable of operating in water depths of up to 250 feet, one in water depths
of up to 230 feet and one in water depths of up to 200 feet. Two of these rigs
are specially designed with eight-foot drafts to permit them to work in shallow
water depths and are equipped with large cranes which enable them to perform
certain construction activities as well as drilling work.
Jackup rigs often compete with semisubmersible rigs in water depths ranging
from 200 to 360 feet, especially in the North Sea. Within this water depth range
in the North Sea, the industry's general preference is to utilize heavy duty
harsh environment jackup rigs for a number of reasons, including cost
effectiveness resulting from operating efficiencies, greater hull stability and
more accessible well control equipment when compared to semisubmersible rigs.
Semisubmersible Rigs. The Company's three semisubmersible rigs are designed
to work in deeper water than jackup rigs. These semisubmersible rigs operate
afloat and include the machinery, quarters and drilling equipment on a deck
structure which is supported by the buoyancy of two submerged barge-shaped
hulls. The Company's semisubmersible rigs are moved between drill sites by
pumping saltwater ballast out of the lower hulls until the rig is raised to its
transit draft. Once the rig is positioned on location by tugs, saltwater ballast
is pumped into the lower hulls until the water level is approximately midway
between hulls and upper deck structure. The Company's semisubmersible rigs are
maintained on station by an eight point mooring system. Two of the Company's
semisubmersible rigs use combination wire rope/chain anchor lines which allow
the rigs to operate in deeper water than would be the case if the anchor lines
were all wire rope. The third rig uses all wire anchor lines. The mooring
systems on the Company's semisubmersible rigs are often preferred for production
drilling to minimize the risk of damaging existing pipelines on the seabed.
All of the Company's semisubmersible rigs are deep water rigs equipped with
top-drives. The Company's semisubmersible rig in Equatorial Guinea, the Aleutian
Key, is capable of operating in water depths of up to 2,000 feet of water. The
Company's semisubmersible rigs in the North Sea (Rig 135) and in the U.S. Gulf
of
8
<PAGE> 11
Mexico (Rig 140) are capable of operating in water depths of up to 2,400 feet
and, with only minor structural modifications, can be upgraded to operate in
water depths of up to 3,000 feet.
Other Marine Rigs. The Company owns and operates one lake barge in
Venezuela and one platform rig in the North Sea. The Company's lake barge is
conventionally anchored and operates afloat in inland waters where water surface
conditions are mild. The platform rig consists of a number of self-contained
drilling equipment packages which, when assembled on a customer's offshore
production platform, make a complete drilling rig.
More detailed information concerning the Company's marine fleet, as of
February 28, 1998, is set forth in the table below:
<TABLE>
<CAPTION>
MAXIMUM MAXIMUM
SERVICE DATE/ WATER DRILLING BLOWOUT
YEAR OF LATEST DEPTH DEPTH PREVENTER
TYPE AND NAME ENHANCEMENT(1) RIG DESIGN ATTRIBUTES(2) (FT) (FT) (PSI)
------------- -------------- ---------- ------------- ------- -------- ---------
<S> <C> <C> <C> <C> <C> <C>
HEAVY DUTY HARSH ENVIRONMENT JACKUP RIGS
Galaxy III.............. 1999 (Scheduled) F&G Universe IC; SO: ATDS: SCR 400 30,000 15,000
Galaxy II............... 1998 (Scheduled) F&G Universe IC; SO; ATDS; SCR 400 30,000 15,000
Magellan................ 1992/1993 F&G Monarch IC; SO; ATDS; SCR 350 30,000 15,000
Galaxy I................ 1991 F&G Universe IC; SO; ATDS; SCR 400 30,000 15,000
Monitor................. 1989 F&G Monarch IC; ATDS; SCR 350 30,000 15,000
Monarch................. 1988/1996 F&G Monarch IC; ATDS: SCR 350 30,000 10,000
SEMISUBMERSIBLE RIGS
Rig 135................. 1983/1989 F&G L-907 PA; ATDS; 3G; SCR 2,400 25,000 15,000
Rig 140................. 1983 F&G L-907 PA; ATDS: 3G; SCR 2,400 25,000 15,000
Aleutian Key............ 1976/1995 F&G 9500 ATDS: 2G; SCR 2,000 25,000 10,000
300-350 FOOT CANTILEVER JACKUP RIGS
Compact Driller......... 1993 MLT 116C IC; TDS; SCR 300 25,000 10,000
Parameswara............. 1993 BMC 300IC IC; SO; TDS; SCR 300 25,000 10,000
Key Hawaii.............. 1983 MODEC JC-300 IC; ATDS: SCR 300 25,000 10,000
Key Singapore........... 1982/1994 MLT 116C IC; TDS; SCR 350 25,000 10,000
Rig 136................. 1982 F&G 780 Mod. II IC; TDS; SCR 300 20,000 10,000
Key Manhattan........... 1980/1996 MLT 116C IC; TDS; SCR 350 25,000 10,000
Galveston Key(3)........ 1978/1988 MLT 84/116C IC; TDS; SCR 300 25,000 10,000
Key Gibraltar........... 1976/1996 MLT 84/116C IC; SO; TDS; SCR 300 25,000 10,000
200-250 FOOT JACKUP RIGS
Rig 134(3).............. 1982 F&G L-780 IC; TDS; SCR 250 20,000 10,000
Rig 141................. 1982 MLT 82SDC IC; TDS; SCR 250 20,000 10,000
Rig 124................. 1980 Mitsui 200C-45 IC; TDS; SCR 250 20,000 10,000
Key Bermuda............. 1980 Mitsui IS; SD; TDS; SCR 200 20,000 10,000
Rig 127................. 1981/1995 F&G L-780 IC; TDS; SCR 250 20,000 10,000
Rig 105................. 1975 MLT 52C IC; TDS; SCR 250 20,000 5,000
Key Victoria............ 1974/1996 MLT 80 IS; SD; TDS; DC/DC 250 20,000 10,000
Rig 103................. 1974/1994 MLT 52C IC; TDS; SCR 250 20,000 10,000
Britannia............... 1968/1987 Breit & Garcia IC; TDS; SCR 230 20,000 10,000
OTHER MARINE RIGS
LAKE BARGE RIG
Rey del Lago............ 1971 Levingston DC/DC 100 12,000 5,000
PLATFORM RIG
Rig 82.................. 1968/1995 National 1320 UE TDS; DC/DC N/A 20,000 5,000
</TABLE>
- ---------------
(1) Indicates year rigs were placed in service by the Company and corresponds to
the year built, except the Parameswara, Monarch and Compact Driller, which
were built in 1983, 1986 and 1992, respectively. The second date, if given,
is the most recent year in which the rig underwent a major upgrade in
capacity and/or a refurbishment which extended its useful working life. In
some cases, such upgrade or refurbishment took place over an extended
period; in those instances, the year given is the year in which the work was
completed.
9
<PAGE> 12
(2) Attributes are abbreviated as follows: "ATDS" means an advanced top drive
system (Varco TDS 4 and above); "DC/DC" means a power transmission system in
which DC electricity is generated by diesel engines and supplied directly to
DC motors driving the principal components of drilling equipment (mud pumps,
draw works, and rotary table); "IC" means independent leg cantilever; "IS"
means independent leg slot rig; "PA" means propulsion assist; "SCR" means a
highly efficient power transmission system which rectifies AC power to DC
power using a silicon controlled rectifier; "SD" means shallow draft; "SO"
means skid-off capability; "TDS" means top drive drilling system; "2G" means
2nd generation semisubmersibles; and "3G" means 3rd generation
semisubmersibles.
(3) The Galveston Key and Rig 134 are owned by P.T. Santa Fe Supraco Indonesia,
a limited liability company of which the Company is an 80% shareholder.
As of December 31, 1997, the average age of the Company's marine fleet,
measured from the date first placed in service by the Company, was 16.4 years.
The average age for heavy duty harsh environment rigs, semisubmersible rigs,
300-350 foot cantilever jackup rigs, 200 to 250 foot jackup rigs and other
marine rigs was 7.3 years, 16.5 years, 14.1 years, 19.9 years and 28.1 years,
respectively.
Land Rigs
The Company had its origins as a U.S. land drilling contractor and was a
pioneer in international land rig operations, especially in the Middle East and
Latin America. Although the Company has emphasized the development of its marine
fleet, it has maintained a substantial presence in selected international land
rig markets and has continuously upgraded, modernized and enhanced its land
rigs. Since the beginning of 1996, the Company has selectively expanded its land
rig fleet. In 1996, five specialized, highly mobile land rigs and two heavy duty
3,000 horsepower rigs equipped with top drives were acquired and contracted to
clients. In early 1998, the Company contracted and placed in service a
specialized highly mobile rig for use in Egypt and initiated acquisition and
assembly of two 2,000 horsepower and two 3,000 horse power land rigs scheduled
for work in Venezuela.
Many of the Company's land rigs are designed for use in remote desert
environments and generally include all necessary facilities to support living
and working in harsh and remote environments, including accommodation camps and
inventories of repair parts and materials. Each of the rigs is designed for
efficient disassembly, transport and reassembly. Eleven of the newer rigs are
specially designed as wheel-mounted units that can be moved quickly between well
locations. The Company's land rig operations in Egypt, Kuwait, the Kuwait-Saudi
Arabia Partitioned Neutral Zone and Qatar are supported by an extensive fleet of
specialized rig transport equipment, comprised primarily of heavy duty trucks
equipped for desert service. Additionally, these operations are supported by a
fleet of heavy equipment, such as bulldozers, cranes and forklifts which prepare
access roads and drill site locations and facilitate the assembly and tear down
of the Company's land rigs.
The Company historically has concentrated its land rig operations in the
Middle East, South America and North Africa. The Company has a longstanding
operational history in these areas, having operated in each of them for over 25
years. As of December 31, 1997, the Company was operating 28 land rigs in
Kuwait, Venezuela, Egypt, Oman, Qatar, the Kuwait-Saudi Arabia Partitioned
Neutral Zone and Saudi Arabia. As of December 31, 1997, the average age of the
Company's land rig fleet, measured from the date first placed in service by the
Company, was 10.8 years.
Information concerning the Company's fleet of land drilling rigs as of
February 28, 1998 is set forth in the table below:
<TABLE>
<CAPTION>
MAXIMUM
DRILLING BLOWOUT
DEPTH PREVENTER
NAME RIG TYPE HORSEPOWER (FT.) (PSI) POWER(1)
---- -------- ---------- -------- --------- --------
<S> <C> <C> <C> <C> <C>
COMPANY OWNED LAND RIGS
Rig 144...................... EMSCO C3 3,000 30,000 10,000 DC/DC
Rig 155...................... Oilwell E-3000 3,000 30,000 15,000 SCR
Rig 173...................... Gardner Denver 3000 3,000 30,000 10,000 SCR
</TABLE>
10
<PAGE> 13
<TABLE>
<CAPTION>
MAXIMUM
DRILLING BLOWOUT
DEPTH PREVENTER
NAME RIG TYPE HORSEPOWER (FT.) (PSI) POWER(1)
---- -------- ---------- -------- --------- --------
<S> <C> <C> <C> <C> <C>
Rig 174...................... EMSCO C3 3,000 30,000 10,000 SCR
Rig 176(2)................... Ideco 3000E 3,000 30,000 10,000 SCR
Rig 177(2)................... Oilwell E-3000 3,000 30,000 10,000 SCR
Rig 162...................... Midco 1220 EB 2,500 30,000 10,000 SCR
Rig 94....................... National E-2000 2,000 20,000 10,000 DC/DC
Rig 97....................... Oilwell E-2000 2,000 20,000 10,000 SCR
Rig 104...................... National 1320 DE 2,000 16,000 10,000 DC/DC
Rig 110...................... Oilwell E-2000 2,000 20,000 5,000 DC/DC
Rig 115...................... National 1320 DE 2,000 20,000 10,000 DC/DC
Rig 119...................... Oilwell E-2000 2,000 20,000 10,000 DC/DC
Rig 158...................... Oilwell E-2000 2,000 25,000 10,000 SCR
Rig 178(2)................... National 1320 2,000 17,000 5,000 SCR
Rig 179(2)................... National 1320 2,000 17,000 5,000 SCR
Rig 157...................... Ideco 1700 UE 1,700 17,000 5,000 SCR
Rig 92....................... National 110 UE 1,500 16,000 5,000 DC/DC
Rig 102...................... National 110 UE 1,500 16,000 5,000 DC/DC
Rig 147...................... National 110 UE 1,500 16,000 5,000 DC/DC
Rig 170...................... National 110 UE 1,500 16,000 5,000 SCR
Rig 169...................... National 110 UE 1,500 16,000 5,000 SCR
Rig 160...................... Dreco 1250 E 1,250 12,000 5,000 SCR
Rig 161...................... Dreco 1250 E 1,250 12,000 5,000 SCR
Rig 150...................... National 80 UE 1,000 12,000 5,000 SCR
Rig 151...................... National 80 UE 1,000 12,000 5,000 SCR
Rig 166...................... Wilson 75 900 10,000 5,000 Mech
Rig 167...................... Wilson 75 900 10,000 5,000 Mech
Rig 146...................... Kremco 750 750 10,000 5,000 SCR
Rig 159...................... Cooper 750 750 8,000 5,000 Mech
Rig 171...................... Oilwell 660-E 750 10,000 5,000 SCR
Rig 172...................... Oilwell 660-E 750 10,000 5,000 SCR
Rig 143...................... Ideco H37 ED 500 6,500 3,000 Mech
JOINT VENTURE OWNED LAND
RIGS(3)
Rig 89....................... National 110 UE 1,500 16,000 10,000 DC/DC
QDC 3........................ Cooper 650 650 8,000 3,000 Mech
Rig 131...................... Portadril 330 1,000 None Mech
</TABLE>
- ---------------
(1) For purposes of this table, "DC/DC" refers to a power transmission system in
which DC electricity is generated by diesel engines and supplied directly to
DC motors driving the principal components of drilling equipment (mud pumps,
drawworks, and rotary table); "Mech" is a power transmission system in which
power to the principal components of drilling equipment (mud pumps,
drawworks and rotary table) is supplied by direct mechanical linkage; and
"SCR" means a highly efficient power transmission system which rectifies AC
power to DC power using a silicon controlled rectifier.
(2) Under assembly.
(3) For purposes of this table, joint ventures refer only to joint ventures
which the Company accounts for on the equity method. The rigs listed are
owned by Qatar Drilling Company W.L.L., of which the Company is a 49%
shareholder.
11
<PAGE> 14
Rig Fleet Utilization
The following table sets forth certain information for the Company's rig
fleet during the six months ended December 31, 1997 and 1996 and each of fiscal
1997, 1996 and 1995.
<TABLE>
<CAPTION>
AVERAGE FOR THE SIX
MONTHS ENDED AVERAGE FOR THE
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
------------------- --------------------------
1997 1996 1997 1996 1995
------- ------- ------ ------ ------
<S> <C> <C> <C> <C> <C>
HEAVY DUTY HARSH ENVIRONMENT JACKUP RIGS
Total rigs(1)................................... 4.0 4.0 4.0 4.0 4.0
Rigs under contract............................. 4.0 4.0 4.0 3.9 3.9
Utilization rate(2)............................. 99.2% 100.0% 99.5% 97.5% 97.9%
SEMISUBMERSIBLE RIGS
Total rigs...................................... 3.0 3.0 3.0 3.0 3.0
Rigs under contract............................. 2.8 3.0 3.0 2.3 2.7
Utilization rate(2)............................. 94.4% 100.0% 100.0% 75.3% 89.0%
300-350 FOOT CANTILEVER JACKUP RIGS(3)
Total rigs...................................... 8.0 7.0 7.5 7.0 7.0
Rigs under contract............................. 7.8 6.5 7.2 6.7 6.4
Utilization rate(2)............................. 97.0% 93.5% 95.5% 95.7% 91.5%
200-250 FOOT JACKUP RIGS(3)
Total rigs...................................... 9.0 10.0 9.5 10.0 10.0
Rigs under contract............................. 9.0 8.6 8.8 8.8 9.2
Utilization rate(2)............................. 100.0% 86.4% 92.1% 88.4% 91.7%
OTHER MARINE RIGS
Total rigs...................................... 2.0 2.0 2.0 2.0 2.7
Rigs under contract............................. 2.0 1.9 1.9 1.4 2.5
Utilization rate(2)............................. 100.0% 93.5% 96.7% 69.3% 94.2%
LAND RIGS
Total rigs...................................... 27.5 23.3 23.8 21.5 21.0
Rigs under contract............................. 25.4 21.4 21.5 20.5 20.4
Utilization rate(2)............................. 92.3% 92.1% 90.6% 95.3% 97.3%
</TABLE>
- ---------------
(1) There are 14 heavy duty harsh environment jackup rigs currently in service
in the industry: Galaxy I, Maersk Endurer, Maersk Gallant, Maersk Giant,
Maersk Guardian, Magellan, Monarch, Monitor, Rowan-Gorilla II,
Rowan-Gorilla III, Rowan-Gorilla IV, Transocean Nordic, West Epsilon and
Ensco 100.
(2) "Utilization" means the percentage of the number of days a drilling rig is
earning a normal daily margin under a customer contract compared to the
total number of days within a specified period.
(3) For the fiscal years ended June 30, 1996 and 1995, "200-250 foot jackup
rigs" means the Company's nine jackup rigs capable of operating in water
depths of up to 200-250 feet and the Key Gibraltar. During the fiscal year
ended June 30, 1997, the Key Gibraltar was converted to a cantilever rig
and extensively upgraded and was reclassified as a 300-350 foot cantilever
jackup rig effective January 1, 1997.
Drilling Related Services
The Company is a leading provider of drilling related services to the
petroleum industry worldwide, including third party rig operations, incentive
drilling, and drilling engineering and project management. These activities
complement the Company's contract drilling business by enabling the Company to
provide an expanded suite of services, thus responding to customer requirements,
and to enhance the utilization and
12
<PAGE> 15
financial performance of its rig fleet. The Company is able to provide these
services with its existing workforce and infrastructure without investing
significant additional capital.
Third Party Rig Operations. The Company's third party rig operations
historically have been concentrated in the North Sea and Venezuela, areas where
the Company also maintains substantial contract drilling operations. This
enables the Company to meet the needs of its customers and to make more
efficient use of its workforce and infrastructure. In September 1996, the
Company expanded its third party rig operations into the emerging market of the
Caspian Sea when it commenced operation and management of the semisubmersible
rig, Dada Gorgud. As of December 31, 1997, the Company operated and maintained
13 platform, land and offshore rigs for third parties. See "-- Joint Venture,
Agency and Sponsorship Relationships and Other Investments" for a further
discussion of Caspian Drilling Company Limited.
The following table lists the location of third party rigs in which the
Company was participating as of February 28, 1998.
<TABLE>
<CAPTION>
TYPE AND NAME RIG TYPE CUSTOMER(1) LOCATION
------------- -------- ----------- --------
<S> <C> <C> <C>
PLATFORM RIGS
Andrew................................ EMSCO BP U.K. North Sea
Clyde................................. Oilwell E-3000 Talisman U.K. North Sea
Fulmar................................ National 1320 UE Shell U.K. North Sea
Kittiwake............................. National E-2000 VDB Shell U.K. North Sea
Magnus................................ National 1625 BP U.K. North Sea
Miller................................ EMSCO C3 BP U.K. North Sea
Nelson................................ EMSCO CE2 Enterprise U.K. North Sea
Thistle............................... Oilwell E-3000 BP U.K. North Sea
Tiffany............................... EMSCO C2 Agip U.K. North Sea
LAND RIGS
CV9................................... Cabot 900 Corpoven Venezuela
CV15.................................. EMSCO 2000 Corpoven Venezuela
CV16.................................. EMSCO 2000 Corpoven Venezuela
SEMISUBMERSIBLE RIGS
Dada Gorgud(2)........................ F&G Pacesetter AIOC Azerbaijan
</TABLE>
- ---------------
(1) Generic designation including affiliates, joint ventures and consortia.
"AIOC" means Azerbaijan International Operating Company.
(2) Rig is operated by Caspian Drilling Company Limited of which the Company is
a 45% shareholder.
Incentive Drilling Services and Alliances. The Company selectively pursues
incentive drilling contracts and innovative contracting opportunities. In doing
so, the Company seeks markets which enable it to enhance its profitability by
undertaking work that rewards superior performance and drilling productivity.
Types of incentive contracts include:
Turnkey. The Company generally provides all services, drill bits,
casings, well consumables and logistical support to drill a well to a
specified depth for a fixed price.
Footage. The Company receives a predetermined lump sum per foot
drilled in a well or a specified portion thereof.
Well Target Time. The contract provides that the drilling of a
specified well (or portion thereof) is subject to an agreed target time. If
the well is drilled ahead of schedule, then a bonus is paid in accordance
with a specified formula. If the well is drilled behind schedule, a penalty
may be imposed.
Lump Sum or Bonus Arrangement. This arrangement provides for the
Company to perform a specific task either for a lump sum payment or for a
day rate with a bonus payable for time saved.
13
<PAGE> 16
Alliances. An agreement under which the Company works in conjunction
with the customer and selected parties, such as service companies,
fabricators, designers and engineers, to provide and coordinate their
resources, facilities and expertise to maximize efficiency on a specified
drilling project. Alliances often involve common goals and targets, with an
incentive for execution of a project in an efficient manner as measured
against specific time and economic goals. The Company has participated in
alliances involving execution of specified drilling programs as well as an
alliance involving various aspects of engineering, design and procurement
of platform rig equipment for a specific development drilling project.
Drilling Engineering and Drilling Project Management. The Company's
drilling engineers and other engineering personnel provide drilling management
services for its own operations and on a contract basis for customer projects.
Drilling management may involve well design, logistics planning, drilling
process management and analysis of performance. The Company also offers its
customers fully integrated services encompassing the selection and management of
all subcontracted drilling services, which may include procurement and logistics
support, so as to optimize and coordinate the selection and management of
equipment, materials and service personnel for a specified drilling project.
Additionally, the Company provides drilling rig project management, including
rig design, engineering, procurement and commissioning activities as well as
management of all phases of offshore rig new construction or upgrade projects.
COMPETITION
The contract drilling industry is characterized by intense competition.
Competition is usually restricted to a particular region, although drilling rigs
are mobile and can be moved from one region to another in response to changes in
demand. While price is the most important competitive determinant in the
drilling industry, the availability and location of suitable equipment, the
design and technical capability of drilling rigs, and the reputation and
experience of the drilling contractor may also play a significant role in
obtaining a contract and may, in certain cases, warrant a contractor receiving
greater compensation than a competitor. Other competitive factors include the
ability to provide specialized services, such as well drilling engineering, the
technical and financial flexibility to perform turnkey and other incentive
contracts, and the contractor's reputation and safety record. The Company
believes that it competes favorably with respect to all of these factors.
CONTRACTS
Drilling contracts are most often awarded through competitive bidding;
however, some contracts are a result of direct negotiations between the drilling
contractor and the customer. In many cases, the specifications of the bid
contain certain requirements not met by any of the Company's available rigs. As
a result, if the Company is awarded the contract, the Company may incur
considerable expense to upgrade and outfit a rig in the specified manner.
The Company operates each of its rigs under a contract either to drill a
specified well or number of wells or for a stated period of time, which
generally is automatically extended to include the period required to complete
the well in progress on the scheduled contract expiration date. Contracts often
are cancelable upon specified notice at the option of the customer, and some,
but not all, contracts provide for the customer to pay a specified early
termination payment in the event of such cancellation. The contracts customarily
provide for either automatic termination or termination at the option of the
customer in the event of total loss of the drilling rig or if drilling
operations are suspended for extended periods by reason of force majeure or
excessive rig downtime for repairs.
Many of the Company's contracts provide for compensation on a dayrate
basis, under which the Company receives a fixed amount per day that the rig is
operating under contract. Under a dayrate contract, the Company provides the
drilling rig and personnel to operate the rig and to conduct the drilling
operations. Operating expenses, such as crew wages and incidental supplies, with
respect to the contracted rig are paid by the Company. Many of the Company's
dayrate contracts also contain incentive terms which provide for additional
remuneration if specified performance goals are met and sometimes provide for
penalties in the
14
<PAGE> 17
form of reduced or suspended compensation if the specified goals are not
achieved. The Company also provides turnkey, footage and other services on an
incentive contract basis. See "-- Incentive Drilling Services and Alliances"
above.
The rate of compensation specified in each contract depends on the type of
equipment required, its availability and location, the location and nature of
the operation to be performed, the duration of the work, market conditions and
other variables. The contracts generally provide for a reduced dayrate or lump
sum payment when the rig is being transported to or from the first and last
drill site. Generally, a reduced dayrate or no payment is applicable when
operations are suspended because of force majeure or extended mechanical
breakdown. Reduced dayrates often also apply while a rig is on standby awaiting
a customer's directions or customer-furnished materials or services or while
moving between well locations under the same contract. When drilling rigs are
being relocated a substantial distance, the Company attempts to obtain either a
lump sum or a dayrate plus transport costs as compensation for mobilization and
demobilization expenses and the rig time incurred during the period of transit.
The Company's contracts generally provide for payment in dollars except for
amounts required to meet local expenses.
Contracts commonly contain renewal or extension provisions exercisable at
the option of the customer which address extension for a number of wells or
specified period of time. These options may provide that the compensation for
the extension period must be agreed upon before commencement of the extension or
the parties may have negotiated the extension period compensation at the time of
the initial contract. The Company prefers either to negotiate provisions which
require mutual agreement upon compensation for the option term (to obtain
then-prevailing market rates) or establish a means of increasing compensation
for the option term to reflect cost escalation and anticipated market
conditions.
Contract information concerning the Company's marine and land drilling
fleet, as of December 31, 1997, is set forth in the table below:
<TABLE>
<CAPTION>
CURRENT
CONTRACT
TYPE AND NAME LOCATION CUSTOMER(1) EXPIRATION(2)
------------- -------- ----------- -------------
<S> <C> <C> <C>
HEAVY DUTY HARSH ENVIRONMENT
JACKUP RIGS
(Under
Galaxy III................ Construction) Amoco Sep 02
(Under
Galaxy II................. Construction) Mobil Nov 03
Magellan.................. U.K. North Sea Shipyard (3)
Galaxy I.................. U.K. North Sea Elf Mar 01
Monitor................... U.K. North Sea Texaco Jun 99
Monarch................... U.K. North Sea BP Mar 99
SEMISUBMERSIBLE RIGS
Rig 135................... U.K. North Sea Lasmo Sep 98
Rig 140................... U.S. Gulf of Mexico Amerada Hess Jan 98
Aleutian Key.............. Equatorial Guinea Mobil Aug 98
300-350 FOOT CANTILEVER
JACKUP RIGS
Compact Driller........... Gabon Marathon Jun 98
Parameswara............... Australia RBT Group Apr 98
Key Hawaii................ Egypt SUCO Jan 98
Key Singapore............. Egypt Agip Jan 98
Rig 136................... Tunisia Various Apr 98
Key Manhattan............. Egypt Agiba Apr 98
Galveston Key............. Indonesia Unocal Nov 98
Key Gibraltar............. Malaysia Shell Apr 99
</TABLE>
15
<PAGE> 18
<TABLE>
<CAPTION>
CURRENT
CONTRACT
TYPE AND NAME LOCATION CUSTOMER(1) EXPIRATION(2)
------------- -------- ----------- -------------
<S> <C> <C> <C>
200-250 FOOT JACKUP RIGS
Rig 134................... Indonesia Arco Jan 99
Rig 141................... Egypt SUCO Nov 98
Rig 124................... Egypt Petrobel Jan 98
Key Bermuda............... Nigeria Chevron Oct 98
Rig 127................... Qatar Occidental Sep 98
Rig 105................... Egypt Petrobel Dec 98
Key Victoria.............. Venezuela BP Apr 98
Rig 103................... Qatar QGPC Jul 98
Britannia................. U.K. North Sea Shell Jun 98
OTHER MARINE RIGS
LAKE BARGE RIG
Rey del Lago.............. Venezuela Lagoven Jan 98(4)
PLATFORM RIG
Rig 82.................... U.K. North Sea Shell Evergreen
COMPANY OWNED LAND RIGS
Rig 92.................... Egypt Khalda Oct 99
Rig 94.................... Egypt Seagull Jan 98
Rig 104................... Egypt Petrobel Jul 98
Rig 143................... Egypt Petrobel Mar 98
Rig 147................... Egypt Khalda Nov 98
Rig 170................... Egypt Seagull Dec 98
Rig 146................... Kuwait KOC Feb 98
Rig 155................... Kuwait KOC Mar 98
Rig 158................... Kuwait KOC Feb 98
Rig 160................... Kuwait KOC Feb 98
Rig 161................... Kuwait KOC Feb 98
Rig 102................... Kuwait-Saudi PNZ(5) SAT Aug 98
Rig 171................... Kuwait-Saudi PNZ(5) SAT May 99
Rig 144................... Oman PDO Oct 98
Rig 150................... Oman PDO Sep 01
Rig 151................... Oman PDO Apr 99
Rig 159................... Oman PDO Nov 98
Rig 157................... Qatar QGPC May 98
Rig 97.................... Venezuela Corpoven Nov 97(7)
Rig 110................... Venezuela Corpoven Jan 98
Rig 115................... Venezuela Corpoven Mar 98
Rig 119................... Venezuela Corpoven Mar 98
Rig 166................... Venezuela Idle
Rig 167................... Venezuela Idle
Rig 162................... Saudi Arabia Saudi ARAMCO Feb 00
Rig 172................... Kuwait-Saudi PNZ(5) PNZ Dev. Group Apr 98
Rig 173................... Saudi Arabia Saudi ARAMCO May 00
Rig 174................... Saudi Arabia Saudi ARAMCO May 00
JOINT VENTURE OWNED LAND
RIGS(6)
Rig 89.................... Qatar QGPC May 98
QDC 3..................... Qatar Idle
Rig 131................... Qatar QGPC May 98
</TABLE>
16
<PAGE> 19
- ---------------
(1) Generic designation including affiliates, joint ventures and consortia.
"Various" means British Gas Tunisia, Ltd; Union Texas Maghreb, Inc.; Maxus
Tunisia, Inc.; South Kerkennah Oil Company; Marathon Petroleum Tunisia,
Ltd.; and M.P. Zarat Ltd; "GUPCO" means Gulf of Suez Petroleum Company;
"SUCO" means Suez Oil Company; "QGPC" means Qatar General Petroleum Company;
"KOC" means Kuwait Oil Company, K.S.C.; "SAT" means Saudi Arabia Texaco;
"PDO" means Petroleum Development Oman.
(2) Indicates date of scheduled expiration of current contract term, or, if the
contract is for a fixed number of wells, date of estimated completion of
those wells at December 31, 1997. Upon scheduled expiration of the contract
term, most contracts specify automatic continuation for completion of the
well in progress. Many contracts are subject to early termination. The
Magellan, Rig 140, Key Hawaii, Key Singapore, Rig 124, Rig 94, Rig 146, Rig
155, Rig 158, Rig 160 and Rig 161 are subject to additional contracts
already in place for future periods expiring May 2000, April 1998, April
1998, August 1998, July 1998, July 1998, March 2001, March 2001, March 2001,
March 2001 and March 2001, respectively. Many of the Company's contracts
contain term extension options granting the customer the right to extend the
contract term upon advance notice. Some options are at rates specified in
the contract while other options are subject to mutual agreement of the
parties with respect to the rates applicable to the extension term. The
Monitor, Monarch, Rig 103, Rig 144 and Rig 151 are subject to customer term
extension options which specify dayrates for periods expiring May 1999,
February 2001, June 1999, October 1999 and April 2000, respectively.
(3) Rig in shipyard December 25, 1997 to January 23, 1998, then to contract with
Elf expiring May 2000.
(4) Rig continues to work under 90-day interim extension while negotiating
one-year contract extension.
(5) Kuwait-Saudi Arabia Partitioned Neutral Zone.
(6) For purposes of this table, joint ventures refer only to joint ventures
which the Company accounts for on the equity method. The rigs listed are
owned by Qatar Drilling Company W.L.L., of which the Company is a 49%
shareholder. Rig 131 supports other land rig operations in Qatar, primarily
by drilling water wells, and generally is not subject to a separate
contract.
(7) Rig continues to work through completion of well in progress, which is
estimated to be March 1998.
CUSTOMERS
The Company's customers consist primarily of major international, state
owned and large independent oil companies and their affiliates. During the six
months ended December 31, 1997, Royal Dutch/Shell Group of Companies and its
affiliates, joint ventures and consortia accounted for 13.9% of the Company's
consolidated revenues. See Note 11 of the Notes to Consolidated Financial
Statements.
EMPLOYEES
As of December 31, 1997, the Company had approximately 5,600 full time
employees from more than 45 nations, over 95% of whom work outside the United
States. Approximately two-thirds of the Company's employees are citizens of
countries outside North America and Europe. Approximately 600 and 125 of the
Company's employees in Venezuela and Nigeria, respectively, and approximately
100 of the personnel on the Company's rig in Australia, are represented by labor
unions. The Company considers its relations with its employees to be good.
JOINT VENTURE, AGENCY AND SPONSORSHIP RELATIONSHIPS AND OTHER INVESTMENTS
In some areas of the world, local custom and practice or governmental
requirements are such as to necessitate the formation of joint ventures with
local participation. The Company is an active participant in several joint
venture drilling companies, principally in Indonesia, Malaysia, Nigeria, Qatar,
Saudi Arabia and Oman. The Company recently participated in the formation of a
new joint venture company, Caspian Drilling Company Limited, in association with
a rig-owning governmental entity in Azerbaijan. The Company owns 45% of the
shares of Caspian Drilling Company Limited, which entered into approximate ten
year bareboat
17
<PAGE> 20
charters of the semi-submersible rigs Shelf 5 and Dada Gorgud in 1997 and will
operate the rigs under contracts in the Caspian Sea. The Shelf 5 bareboat
charter will commence upon completion of rig upgrades, estimated to occur in the
first calendar quarter of 1999.
The Company participates in a joint venture which operates a petroleum
supply base in Indonesia. The Indonesian supply base, 42% owned by the Company,
is located at Merak Point on West Java. It provides open and covered storage and
bulk chemical trans-shipment facilities. The Company has managed this supply
base for over 25 years. The land lease for the supply base is scheduled to
expire in 2000 and there is no assurance that the lease will be renewed on terms
acceptable to the Company. The Company also has a passive minority investment in
a Libyan drilling company which is accounted for on the cost basis.
Local law or custom in some areas of the world also effectively mandates
establishment of a relationship with a local agent or sponsor. When necessary in
these areas, the Company enters into agency or sponsorship agreements.
RISKS, INSURANCE AND INDEMNIFICATION
The Company emphasizes ongoing safety and training programs and has
installed significant safety equipment, all designed to promote a safe working
environment. Nevertheless, the operations of the Company are subject to the many
hazards inherent in the drilling business.
While the Company maintains broad insurance coverage, such insurance
generally does not cover all types of losses (e.g., war, internal disturbances,
expropriation, nationalization or business interruption). Losses and liabilities
arising from uninsured or underinsured events would reduce revenues and increase
costs to the Company. In addition, pollution and similar environmental risks
generally are not fully insurable. As a consequence, the existing insurance may
not be sufficient to protect the Company from all of its operational risks or
against liability from all consequences of well disasters, maritime casualties
or damage to the environment. It is also not sufficient to protect the Company
for the full market or replacement value of assets that are rendered actual or
constructive total losses. The Company may be liable for oil spills, costs of
controlling a wild well, well loss or damage and similar matters if not
indemnified by its customers or insured. When appropriate, the Company may
separately insure well-related risks (well loss or damage, wild well control and
pollution).
The Company believes its policy with regard to the purchase of insurance
coverage is consistent with industry practice with regard to the types, amounts
and limits of insurance maintained. Under current conditions, the Company
anticipates that its present insurance coverages will be maintained, but no
assurances can be given that the insurance coverages will continue to be
available at rates considered reasonable or that certain types of coverage will
be available at any cost.
In the event insurance is determined to be inadequate or unavailable, the
Company evaluates its exposure to uninsurable risks before participating in any
projects. To the extent permitted by market conditions, the Company contracts
with its customers to provide the Company with indemnification or other
protection against risks not generally covered by insurance and against losses
in excess of applicable insurance limits. The Company generally has been able to
obtain contractual indemnification from its customers which protects and
indemnifies the Company to some degree from liability arising out of damages to
customer property and injuries to certain personnel, reservoir, pollution and
environmental damages and wild well control. However, there can be no assurance
that the Company can obtain such indemnification in all of its contracts.
ITEM 2. DESCRIPTION OF PROPERTY.
See "Item 1. Description of Business -- Drilling Rig Fleet and Drilling
Related Services" for a description of the Company's principal assets. The
Company leases and, in some cases, owns various operating and administrative
facilities, generally consisting of office, maintenance and storage space,
around the world.
18
<PAGE> 21
ITEM 3. LEGAL PROCEEDINGS.
The Company is involved in various legal proceedings incidental to its
business. In the opinion of the management of the Company, based upon
information presently available, the ultimate resolution of these legal
proceedings will not have a material adverse effect on the financial condition
or results of operations of the Company.
The Company has been named as a Potentially Responsible Party ("PRP") in
connection with a Superfund site located in Whittier, California maintained by
Waste Disposal, Inc. ("WDI"). On August 18, 1994 the U.S. Environmental
Protection Agency (the "EPA") issued an Administrative Order for Remedial Design
("ORD") against eight PRPs, not including the Company, alleging that they are
responsible for costs associated with the cleanup of the WDI site and requesting
that these parties consent to undertake certain specific investigative and
remedial measures with respect to the site. On March 31, 1997 the ORD was
amended to modify the scope of remedial work to be performed at the site and to
add thirteen additional parties, including the Company. On April 29, 1997 the
Company advised the EPA of its intention to comply with the ORD. In an effort to
minimize costs associated with its involvement in the site, the Company has
entered into a Participation Agreement with the other named PRPs, by which the
PRPs will provide monetary credit to certain PRPs for previously incurred costs,
cooperate in common response to any claims arising out of the ORD, and allocate
among themselves costs associated with their involvement with the site. On July
9, 1997 the PRPs tentatively agreed to an allocation arrangement, which, subject
to anticipated appeals by certain PRPs, the Company believes will be concluded
in the near future. In addition, ultimate liability will be dependent upon the
results of on site testing currently underway and agreement between the EPA and
the PRPs concerning the most cost effective and appropriate remediation of the
site.
Based on information presently available, the Company does not believe that
any liability imposed in connection with the WDI site will have a material
adverse effect on the Company's financial condition or ongoing results or
operations given the nature and extent of its involvement at the site and
available resources.
ITEM 4. CONTROL OF REGISTRANT.
(a) As of February 28, 1998, Holdings, a wholly-owned subsidiary of KPC,
beneficially owned approximately 64.9% of the outstanding Ordinary Shares. KPC
is wholly-owned by the Government of Kuwait.
So long as Holdings owns a majority of the outstanding Ordinary Shares, KPC
through Holdings will be able to elect the Board of Directors of the Company and
effectively control the outcome of the vote on certain matters submitted to a
vote of the Company's shareholders. Mr. Nader Hamad Sultan, a Director of the
Company who also serves as Chairman and a member of the Board of Holdings, has
been authorized by the Holdings Board to cast votes for Holdings' Ordinary
Shares of the Company at the Company's 1998 Annual General Meeting of
Shareholders, in person or by proxy. So long as KPC remains a significant
indirect shareholder of the Company, it intends to oversee its investment in the
Company, including pursuant to its and Holdings' rights under the Intercompany
Agreement and the Company's Articles. See "Item 13. Interest of Management in
Certain Transactions."
(b) The following table is furnished as of February 28, 1998 to indicate
beneficial ownership of the Company's Ordinary Shares by (i) each person who is
known by the Company to be a beneficial owner of more than 5% of the Company's
Ordinary Shares and (ii) all executive officers and Directors of the Company as
a group. The information in the following table was provided by such persons.
<TABLE>
<CAPTION>
TITLE OF CLASS IDENTITY OF PERSON OR GROUP AMOUNT OWNED PERCENT OF CLASS
-------------- --------------------------- ------------ ----------------
<S> <C> <C> <C>
Ordinary Shares........... SFIC Holdings (Cayman), Inc. 74,500,000 64.9%
Ordinary Shares........... Directors and Executive Officers as a group
(18 persons) 118,984(1) 0.1%
</TABLE>
- ---------------
(1) Does not include 107,600 restricted shares or 327,650 options that are not
exercisable within 60 days. Includes 19,684 shares held in the Company's
Investment Savings and Profit Sharing Plan and 250
19
<PAGE> 22
shares held by a spouse in a custodial account for the benefit of a minor
child. Does not include 4,000 shares held of record by the spouse of Mr.
Ferdinand A. Berger, a Director of the Company. Mr. Berger disclaims
beneficial ownership of such 4,000 shares. Does not include 74,500,000
shares over which Mr. Nader Hamad Sultan has the authority to cast votes on
behalf of Holdings at the Company's 1998 Annual General Meeting of
Shareholders. Mr. Sultan disclaims beneficial ownership of such 74,500,000
shares.
ITEM 5. NATURE OF TRADING MARKET.
There is no non-U.S. trading market for the Ordinary Shares of the Company.
Within the United States, effective June 10, 1997 the Company's Ordinary
Shares commenced trading on The New York Stock Exchange ("NYSE") under the
symbol "SDC."
The following table sets forth the high and low sales price per Ordinary
Share for each quarterly fiscal period since trading of the Ordinary Shares on
the NYSE commenced.
<TABLE>
<CAPTION>
HIGH LOW
---- ---
<S> <C> <C>
FISCAL YEAR ENDED JUNE 30, 1997:
Fourth Quarter (commencing June 10, 1997)................. $34.63 $31.00
TRANSITION PERIOD FROM JULY 1, 1997 TO DECEMBER 31, 1997:
First Quarter............................................. $48.75 $33.50
Second Quarter............................................ $57.00 $35.00
CALENDAR YEAR 1998
First Quarter (through February 28, 1998)................. $41.50 $33.50
</TABLE>
Based upon records maintained by its transfer agent, as of February 28,
1998, there were approximately 245 shareholders of record in the United States
and 241 shareholders of record outside of the United States holding
approximately 40,148,557 and 74,623,423 Ordinary Shares, respectively. These
numbers include persons or entities holding shares as nominees for beneficial
owners.
On March 25, 1998, the Company's Board of Directors declared a quarterly
dividend of $0.0325 per Ordinary Share payable on April 15, 1998 to holders of
record at the close of business March 31, 1998. The Company's current dividend
policy contemplates the payment of quarterly dividends of $0.0325 per Ordinary
Share.
ITEM 6. EXCHANGE CONTROLS AND OTHER LIMITATIONS AFFECTING SECURITY HOLDERS.
The Company is not subject to any governmental laws, decrees or regulations
in the Cayman Islands which restrict the export or import of capital, including
any foreign exchange controls, or which affect the remittance of dividends,
interest or other payments to non-resident holders of the Company's Ordinary
Shares.
Additionally, neither the laws of the Cayman Islands nor the Company's
charter impose any limitations on the right of non-resident foreign owners to
hold or vote the Ordinary Shares of the Company.
ITEM 7. TAXATION.
At the present time there is no Cayman Islands income or profits tax,
withholding tax, capital gains tax, capital transfer tax, estate duty or
inheritance tax payable by a Cayman Islands company or its shareholders. The
Company has obtained an assurance from the Cayman Islands Government under the
Tax Concessions Law (Revised) that, in the event that any legislation is enacted
in the Cayman Islands imposing tax computed on profits or income, or computed on
any capital assets, gain or appreciation, or any tax in the nature of estate
duty or inheritance tax, such tax shall not until February 13, 2010 be
applicable to the Company or to any of its operations or to the shares,
debentures or other obligations of the Company. Therefore, under present law
there will be no Cayman Islands tax consequences with respect to distributions
in respect to the Ordinary Shares. The United States does not have a tax treaty
with the Cayman Islands. See "Item 1. Description of Business -- Business
Considerations and Risk Factors -- Taxation Risks."
20
<PAGE> 23
ITEM 8. SELECTED CONSOLIDATED FINANCIAL DATA.
The following table sets forth selected consolidated financial data for the
Company as of and for the six months ended December 31, 1997 and 1996 and for
each of the five fiscal years in the period ended June 30, 1997, which has been
derived from audited financial statements of the Company. Audited financial
statements for the six months ended December 31, 1997 and 1996 and the three
years in the period ended June 30, 1997, 1996 and 1995 are included elsewhere in
this Transition Report on Form 20-F. The Company currently operates in one
business segment, providing contract drilling and drilling related services
throughout the world. The information set forth below should be read in
conjunction with "Item 9. Management's Discussion and Analysis of Financial
Condition and Results of Operations" and the Consolidated Financial Statements
and notes thereto.
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
-------------------- -------------------------------------------------------
1997 1996 1997 1996 1995 1994 1993
--------- -------- ---------- --------- -------- -------- --------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA:
Operating revenues...................... $ 375,185 $264,791 $ 578,563 $ 470,882 $466,262 $391,752 $367,703
Operating costs and expenses:
Operating costs....................... 195,678 161,510 339,665 308,513 320,317 271,951 263,389
Depreciation and amortization(1)...... 24,876 22,039 43,360 77,128 86,916 87,460 84,606
General and administrative............ 10,781 7,563 16,931 17,168 16,225 14,676 15,056
Loss (gain) on sale of assets......... (374) (789) (1,041) (754) (1,355) (2,176) 4,850
--------- -------- ---------- --------- -------- -------- --------
Total operating expenses........ 230,961 190,323 398,915 402,055 422,103 371,911 367,901
Operating income (loss)................. 144,224 74,468 179,648 68,827 44,159 19,841 (198)
Other income (expense), net............. 804 4,529 6,593 9,016 5,094 (1,336) (1,821)
--------- -------- ---------- --------- -------- -------- --------
Income before provision for taxes
on income............................. 145,028 78,997 186,241 77,843 49,253 18,505 (2,019)
Provision for taxes on income........... 16,500 10,339 21,325 15,867 4,955 8,007 6,204
--------- -------- ---------- --------- -------- -------- --------
Net income (loss)....................... $ 128,528 $ 68,658 $ 164,916 $ 61,976 $ 44,298 $ 10,498 $ (8,223)
========= ======== ========== ========= ======== ======== ========
Income per ordinary share(2):
Basic................................. $ 1.12 $ 1.44
Diluted............................... $ 1.12 $ 1.44
Pro forma net income per ordinary
share(2):
Basic................................. $ 0.60 $ 0.54
Diluted............................... $ 0.60 $ 0.54
Cash dividends per ordinary share(3).... $ 0.065 $ -- $ -- $ --
========= ======== ========== =========
OTHER FINANCIAL DATA:
Capital expenditures.................... $ 127,133 $ 44,537 $ 146,596 $ 64,810 $ 36,443 $ 44,527 $ 60,324
Cash flows provided by (used in):
Operating activities.................. 164,669 74,053 207,178 113,118 131,685 82,326 124,836
Investing activities.................. (131,428) (38,977) (143,197) 5,012 (14,643) (17,781) (38,777)
Financing activities.................. (3,721) (3,829) (66,893) (108,391) (98,373) (69,756) (87,874)
EBITDA(4)............................... 169,100 96,507 223,008 145,955 131,075 107,301 84,408
BALANCE SHEET DATA:
Working capital......................... $ 122,700 $172,627 $ 125,730 $ 124,333 $ 89,033 $ 73,466 $ 87,269
Property and equipment, net............. 801,970 610,216 691,300 587,420 599,680 652,202 699,899
Total assets............................ 1,161,453 948,232 1,000,446 884,998 924,983 938,206 986,294
Total debt(5)........................... -- -- -- -- 58,364 84,254 107,509
Shareholders' equity.................... 953,017 797,921 831,115 733,092 728,089 755,253 785,331
</TABLE>
- ---------------
(1) During 1996, the Company's management undertook engineering and economic
studies to evaluate the economic useful lives of its drilling rigs. The
study results indicated that the estimated useful lives should be extended
by 12 years from 18 to 30 years for marine rigs and by four years from 12 to
16 years for land rigs. The Company's Board of Directors approved
application of the change in estimated useful lives effective July 1, 1996
which reduced depreciation expense, and increased net income, by
approximately $34.5 million for the fiscal year ended June 30, 1997. See
Note 3 of the Notes to Consolidated Financial Statements.
21
<PAGE> 24
(2) The basic income per Ordinary Share data for the six months ended December
31, 1997 and the fiscal year ended June 30, 1997 is calculated based on
weighted average shares outstanding for the periods of 114,500,000. The
dilutive impact of Ordinary Share equivalents related to stock awards and
options outstanding under the Company's share award plans was not
significant for the periods presented, increasing the weighted average
shares outstanding used in the computation for the six months ended December
31, 1997 and the fiscal year ended June 30, 1997 to 114,608,000 and
114,502,000, respectively. The pro forma net income per Ordinary Share data
for the six months ended December 31, 1996 and the fiscal year ended June
30, 1996 is calculated as though 114,500,000 shares issued were outstanding.
See Note 2 of the Notes to Consolidated Financial Statements.
(3) Prior to becoming a public company, the Company made certain distributions
to its sole shareholder.
(4) EBITDA (Operating Income before depreciation) is a supplemental financial
measure used by the Company in evaluating its business and should be read in
conjunction with all the information in the Consolidated Financial
Statements and notes thereto included elsewhere herein. The Company believes
that EBITDA is a measure commonly used by analysts, investors and others
interested in the contract drilling industry. Accordingly, this information
has been disclosed herein to permit a more complete analysis of the
Company's operating performance. The difference between cash flows provided
by operating activities and EBITDA relates to interest, taxes, depreciation
and changes in operating assets and liabilities. EBITDA should not be
considered as an alternative to net income or cash flow from operating
activities or as an indication of the Company's performance or as a measure
of liquidity. The Company's definition of EBITDA may not be comparable with
similarly titled measures disclosed by other companies.
(5) Total debt related to rigs held under leveraged capitalized lease
obligations. During 1996 and 1994 the Company acquired the equity owner's
interest in such rigs and extinguished the related obligations during 1996
and 1995.
ITEM 9.MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
The following discussion should be read in conjunction with the Company's
Consolidated Financial Statements and notes thereto, included elsewhere in this
Transition Report on Form 20-F.
CHANGE IN FISCAL YEAR
At the direction of its Board of Directors, the Company has implemented a
change from a June 30 fiscal year end to a December 31 fiscal year end effective
January 1, 1998. Consequently, this Transition Report covers the period from
July 1, 1997 to December 31, 1997 except as otherwise noted herein.
RESULTS OF OPERATIONS
General
Overview. Offshore contract drilling industry conditions, and resulting
offshore drilling rig utilization and dayrates, have improved substantially
since the beginning of 1995, while land rig dayrates during that period have
been relatively stable in the markets in which the Company operates. The
Company's contract drilling revenues vary based upon demand, which affects the
number of days the rig fleet is utilized and the dayrates received. Revenue can
also increase or decrease as a result of the acquisition or disposal of rigs. In
order to improve utilization or realize higher dayrates, the Company may
mobilize its rigs from one market to another. During periods of mobilization,
however, revenues generally are adversely affected. As a response to changes in
demand and dayrate conditions, the Company may withdraw a rig from the market by
"stacking" it in an idle mode or may reactivate a rig which was previously
stacked, which may decrease or increase revenues, respectively. See "Item 1.
Description of Business -- Industry Conditions." See "-- Liquidity and Capital
Resources -- Industry Risks" for a description of certain factors that may
affect the Company's results of operations in the future.
Operating revenues. Santa Fe derives its revenues from dayrates under
drilling contracts and the provision of drilling related services. A drilling
contract may provide both dayrate and drilling related service
22
<PAGE> 25
revenues. Changes in or renewals of contracts may alter the composition of the
Company's revenues. Revenues from dayrate drilling contracts are recognized as
work is performed. When mobilization or rig enhancement is required for a
contract, the Company may receive a lump-sum payment to offset all or a portion
of the cost. When an offshore rig is mobilized from one market to another under
contract, mobilization revenues less costs incurred are recognized over the term
of the related drilling contract. If a rig is moved without a contract, all
costs incurred are immediately charged against income. Payments received for rig
enhancements are recognized as revenues over the term of the related drilling
contract. In addition to the impact of dayrates, which increase and decrease
with demand, revenues from contract drilling may fluctuate from quarter to
quarter due to the timing of contract completions, mobilizations, scheduled
maintenance, and the weather.
The Company also earns revenue by providing drilling related services to
the petroleum industry worldwide, including third party rig operations,
incentive drilling, drilling engineering and project management. Revenues from
third party rig operations and drilling engineering services are recognized as
the services are performed. Revenues from incentive drilling are derived from
performance based contracts, including turnkey and footage contracts, in which
the Company has negotiated the opportunity to earn incremental revenue by
meeting or exceeding certain preset job performance criteria. Incremental
revenues from incentive drilling contracts are recognized as terms and
conditions of each contract are fulfilled. The Company uses the percentage of
completion method to account for project management contracts. Revenues from
drilling services fluctuate from quarter to quarter as a result of the amount of
services being performed during the quarter and the timing of achievement of
performance objectives under incentive based and project management contracts.
Operating costs. Operating costs are not affected by changes in dayrates,
nor are they necessarily significantly affected by fluctuations in utilization.
For instance, if a rig is idle for a short period of time, the Company realizes
few decreases in operating expenses since the rig typically is maintained in a
ready-to-operate state with a full crew. However, if a rig were expected to be
idle for more than a brief period of time, the Company could reduce the size of
the rig's crew and take steps to maintain the rig in an idle "stacked" mode,
which lowers expenses and partially offsets the negative impact on operating
income associated with loss of revenues. Operating costs also may be impacted by
the Company's ability to successfully hire and train sufficient numbers of
employees to operate the Company's drilling equipment. The Company recognizes as
an operating cost repair and maintenance activities, such as painting,
inspections and routine overhauls that maintain rather than upgrade the rigs.
These expenses include the purchase of parts and materials from third parties,
the prices of which vary from period to period and are, in part, impacted by
influences outside the control of the Company. Recently, the Company has
experienced significant increases in the cost of rig related equipment and spare
parts due to manufacturer/supplier price increases. The Company's financial
results could be negatively affected in the future by these or similar cost
increases.
Operating income. In addition to operating revenues and costs, operating
income is also affected by the level of general and administrative expense,
depreciation and amortization expense and any gains or losses from the sale or
retirement of assets. Costs of rig enhancements are capitalized and depreciated
over the expected useful lives of the enhancements. Increased depreciation
expense subsequent to a capital upgrade decreases operating income.
Provision for taxes on income. The Company is not subject to income taxes
in the Cayman Islands. The Company's provision for taxes on income for the six
months ended December 31, 1997 and 1996 and the fiscal years ended June 30,
1997, 1996 and 1995 was $16.5 million, $10.3 million, $21.3 million, $15.9
million and $5.0 million, respectively. The Company's effective tax rate for the
six months ended December 31, 1997 and 1996 and the fiscal years ended June 30,
1997, 1996 and 1995 was 11.4%, 13.1%, 11.5%, 20.4% and 10.1%, respectively. The
effective tax rate varies from period to period because each country in which
the Company operates has its own tax system and because the amounts earned in,
and subject to tax by, each jurisdiction change from period to period. The
Company's consolidated pre-tax income has increased while the effective tax rate
has decreased because a substantial portion of the Company's pre-tax income is
either not subject to taxation or is subject to taxation at reduced rates. See
Note 5 of Notes to Consolidated Financial Statements.
23
<PAGE> 26
The following tables present data relating to the Company's operating
revenues, operating costs, operating income, utilization and average dayrates by
equipment type and for drilling services.
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
-------------------- --------------------------------
1997 1996 1997 1996 1995
-------- -------- -------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
OPERATING REVENUES
Heavy duty harsh environment jackup rigs...... $ 71,813 $ 55,623 $119,741 $ 92,939 $ 80,240
Semisubmersible rigs.......................... 49,483 26,447 64,751 37,510 31,736
300-350 foot cantilever jackup rigs(1)........ 66,867 38,786 93,773 65,308 58,963
200-250 foot jackup rigs(1)................... 69,272 42,651 97,141 73,716 75,452
Other marine rigs............................. 5,669 5,639 11,009 4,666 11,670
-------- -------- -------- -------- --------
Total marine rigs.................... 263,104 169,146 386,415 274,139 258,061
-------- -------- -------- -------- --------
Land rigs..................................... 71,626 49,257 103,158 91,859 92,905
Drilling related services..................... 39,596 45,028 86,904 101,581 113,042
Other......................................... 859 1,360 2,086 3,303 2,254
-------- -------- -------- -------- --------
Total operating revenues............. 375,185 264,791 578,563 470,882 466,262
-------- -------- -------- -------- --------
OPERATING COSTS(2)
Heavy duty harsh environment jackup rigs...... 25,224 23,351 45,218 40,528 37,917
Semisubmersible rigs.......................... 22,767 18,042 36,969 30,979 27,410
300-350 foot cantilever jackup rigs(1)........ 30,125 19,380 48,900 39,130 39,889
200-250 foot jackup rigs(1)................... 31,491 31,182 59,552 53,947 53,639
Other marine rigs 4,219 3,151 6,808 3,252 7,870
-------- -------- -------- -------- --------
Total marine rigs.................... 113,826 95,106 197,447 167,836 166,725
-------- -------- -------- -------- --------
Land rigs..................................... 48,345 35,485 73,687 63,689 62,371
Drilling related services..................... 30,537 30,305 61,408 75,775 90,061
Other......................................... 2,970 614 7,123 1,213 1,160
-------- -------- -------- -------- --------
Total operating costs................ 195,678 161,510 339,665 308,513 320,317
-------- -------- -------- -------- --------
Depreciation and amortization................. (24,876) (22,039) (43,360) (77,128) (86,916)
General and administrative.................... (10,781) (7,563) (16,931) (17,168) (16,225)
Gain on sale of assets........................ 374 789 1,041 754 1,355
-------- -------- -------- -------- --------
OPERATING INCOME..................... $144,224 $ 74,468 $179,648 $ 68,827 $ 44,159
======== ======== ======== ======== ========
OPERATING INCOME AS A PERCENTAGE OF
REVENUES.................................... 38.4% 28.1% 31.1% 14.6% 9.5%
======== ======== ======== ======== ========
AVERAGE RIG FLEET UTILIZATION
Heavy duty harsh environment jackup rigs...... 99.2% 100.0% 99.5% 97.5% 97.9%
Semisubmersible rigs.......................... 94.4 100.0 100.0 75.3 89.0
300-350 foot cantilever jackup rigs(1)........ 97.0 93.5 95.5 95.7 91.5
200-250 foot jackup rigs(1)................... 100.0 86.4 92.1 88.4 91.7
Other marine rigs............................. 100.0 93.5 96.7 69.3 94.2
Total marine rigs.................... 98.3 92.5 95.5 88.8 92.5
Land rigs..................................... 92.3 92.1 90.6 95.3 97.3
AVERAGE DAYRATES
Heavy duty harsh environment jackup rigs...... $ 98,374 $ 75,575 $ 82,466 $ 65,129 $ 56,151
Semisubmersible rigs.......................... 94,977 47,911 59,133 45,357 32,550
300-350 foot cantilever jackup rigs(1)........ 46,826 32,214 35,887 26,645 25,219
200-250 foot jackup rigs(1)................... 41,831 26,825 30,404 22,773 22,536
Other marine rigs............................. 15,405 16,392 15,593 9,203 12,468
Total marine rigs.................... 55,944 38,216 42,646 32,446 28,591
Land rigs..................................... 15,331 12,486 13,118 12,264 12,462
</TABLE>
- ---------------
(1) For the fiscal years ended June 30, 1996 and 1995, "200-250 jackup rigs"
means the Company's nine jackup rigs capable of operating in water depths of
up to 200-250 feet and the Key Gibraltar. During the
24
<PAGE> 27
fiscal year ended June 30, 1997, the Key Gibraltar was converted to a
cantilever rig and extensively upgraded and was reclassified as a 300-350
foot cantilever jackup rig effective January 1, 1997.
(2) Exclusive of depreciation which is presented separately below.
SIX MONTHS ENDED DECEMBER 31, 1997 AND 1996
Operating revenues. Total operating revenues increased $110.4 million
(41.7%) principally because of increased revenues from heavy duty harsh
environment jackups, semisubmersibles, 300-350 foot cantilever jackups, 200-250
foot jackups and land rigs, partly offset by reduced revenue from drilling
related services. Revenues from the Company's heavy duty harsh environment
jackup rig fleet, which operated entirely in the North Sea for both six month
periods, increased $16.2 million (29.1%) principally because of a 30.2% increase
in average dayrates. Operating revenues for the Company's three semisubmersibles
increased $23.0 million (87.1%) because of a 98.2% increase in average dayrates,
which increased revenues $24.8 million, partially offset by a 5.6% decrease in
utilization stemming from 31 days idle time for Rig 135 in the North Sea between
contracts, which contributed decreased revenues of $1.8 million. The
semisubmersible rigs were continuously located in the North Sea, Gulf of Mexico
and West Africa during the six months ended December 31, 1997 and 1996. Revenues
from 300-350 foot cantilever jackups increased $28.1 million (72.4%). Nine
million dollars of additional revenue were attributable to the Key Gibraltar
which was fully utilized during the 1997 reporting period. During the comparable
1996 reporting period, the rig was idle in the shipyard undergoing modernization
and addition of a cantilever. Substantially all of the remaining $17.8 million
revenue increase was attributable to increased dayrates. Revenues from 200-250
foot jackup rigs increased $26.6 million (62.4%). The increase was primarily
attributable to a 55.9% increase in average dayrates providing $25.0 million in
increased revenues. A 13.6% increase in 200-250 foot jackup rigs utilization
contributed increased revenues of $1.6 million. Revenues from land rigs
increased by $22.4 million (45.4%). Four new rigs operated in the Middle East in
the six months ended December 31, 1997 as compared with the same period of 1996,
increasing revenues by $13.1 million. The remaining increase of $9.3 million was
primarily attributable to a 16.4% increase in dayrates earned by rigs in service
during both periods. Revenues from drilling related services decreased by $5.4
million (12.1%) primarily because of a $4.7 million (100.0%) decrease in project
management revenues and a $1.7 million (6.9%) decrease in third party rig
operations revenues, partially offset by a $1.0 million (6.9%) increase in
revenues from incentive drilling contracts. Revenues from drilling project
management services decreased primarily due to the completion of a platform rig
construction project in the North Sea. Third party rig operations revenues
decreased mainly due to the inception of a rig sharing agreement in Azerbaijan
for a third party semisubmersible rig, which was operated solely by the Company
during the six months ended December 31, 1996, partially offset by increased
activity in South America. Incentive drilling revenues increased because of an
increase in the number of contracts containing incentive based provisions,
primarily in the North Sea.
Operating costs. Total operating costs increased $37.4 million (22.1%) due
principally to increased costs related to the operations of the Company's marine
fleet and land rigs. The increases in operating costs related to the Company's
heavy duty harsh environment jackup rigs ($1.9 million or 8.0%) resulted
primarily from increased costs of preparing the Magellan and the Galaxy I for
new contracts in the North Sea. Semisubmersibles operating costs increased $4.7
million (26.2%) primarily due to increased mobilization cost associated with Rig
135's new contract in the North Sea and increased repair and maintenance costs
for both Rig 140, operating in the Gulf of Mexico, and Rig 135. Increased costs
of $10.7 million (55.4%) for the 300-350 foot cantilever jackup rigs were
primarily due to increased costs associated with operation of the Key Gibraltar
in Malaysia following its extensive upgrade and reclassification to the 300-350
foot cantilever class of rigs and the Parameswara's and Compact Driller's
deployment to and operations in Australia and West Africa, respectively.
Increased operating costs of $1.1 million (33.9%) for other marine rigs stemmed
mainly from increased costs for the lake barge working in South America
associated with a new collective bargaining agreement which was implemented in
the six months ended December 31, 1997. Operating costs associated with land
rigs increased $12.9 million (36.2%), primarily due to the deployment of four
additional rigs in the Middle East ($8.1 million), increased utilization of rigs
in service during both periods ($1.9 million) and increased costs for rigs
working in South America. During the quarter ended December 31, 1997, the
Company experienced
25
<PAGE> 28
increased pressure on operating costs in the form of competition for skilled
employees resulting in increased salary and wages and significantly increased
prices and delivery delays for vendor equipment and materials. It is likely that
these tendencies will continue in 1998.
General and administrative. General and administrative expense increased
$3.2 million (42.5%) primarily due to increased awards under the Company's
performance based management incentive compensation programs ($1.1 million), a
6% increase in staff levels ($0.6 million) and increased outside Director,
investor relations, legal and other costs associated with becoming a public
company in June 1997.
Depreciation and amortization. Depreciation and amortization expense
increased $2.8 million (12.9%) for the six months ended December 31, 1997 as
compared with the same period in the prior year. Depreciation of four land rigs
placed in service during 1997 yielded increased expense of $2.0 million, with
the remainder of the increase due to depreciation of capital additions to other
rigs and equipment, primarily major upgrades to the Key Gibraltar ($0.9
million).
Other income (expense), net. Total other income (expense), net decreased
$3.7 million for the six months ended December 31, 1997. Investment income
decreased $1.2 million during the six months ended December 31, 1997 due to the
sale of marketable securities, the proceeds of which were invested in capital
and other programs. Foreign exchange gains decreased $2.2 million for the six
months ended December 31, 1997 primarily resulting from unfavorable movements of
the dollar in relation to the pound sterling. Costs related to services provided
under the provisions of the Intercompany Agreement was $0.3 million for the six
months ended December 31, 1997. See "Item 13. Interest of Management in Certain
Transactions -- Related Party Agreements."
Provision for taxes on income. The provision for taxes on income increased
by $6.2 million, primarily due to significantly increased earnings in the U.K.,
Egypt, West Africa and the U.S. For the six months ended December 31, 1997, the
Company's effective tax rate decreased to 11.4% from 13.1% for the six months
ended December 31, 1996 primarily because a substantial portion of the Company's
pre-tax income was either not subject to taxation or was subject to taxation at
reduced rates. See Note 5 of Notes to Consolidated Financial Statements.
Net income. Net income for the six months ended December 31, 1997 increased
$59.8 million (87.2%) to $128.5 million as compared to $68.7 million for the
same period in the prior year. This increase resulted primarily from the
increase of $110.4 million in the Company's operating revenues, partially offset
by increased operating expense of $37.4 million, increased general and
administrative expense of $3.2 million, $2.8 million higher depreciation
expense, lower other income (expense), net of $3.7 million and an increased
provision for income taxes of $6.2 million.
YEARS ENDED JUNE 30, 1997 AND 1996
Operating revenues. Total operating revenues increased $107.7 million
(22.9%) principally because of increased revenues from heavy duty harsh
environment jackups, semisubmersibles, 300-350 foot cantilever jackups, 200-250
foot jackups, other marine, and land rigs, partly offset by reduced revenue from
drilling related services. Revenues from the Company's heavy duty harsh
environment jackup rig fleet increased $26.8 million (28.8%) principally because
of continued high demand (99.5% utilization) for high quality jackup equipment
in the North Sea and a 26.6% increase in average dayrates. All of the Company's
heavy duty harsh environment jackup rigs were located in the North Sea during
fiscal year 1997. Operating revenues for the Company's three semisubmersibles
increased $27.2 million (72.6%) because of a 30.4% increase in average dayrates,
which increased revenues $15.1 million, and a 32.8% increase in utilization
contributing increased revenues of $12.1 million. The rigs were continuously
located in the North Sea, Gulf of Mexico and West Africa during fiscal year
1997. Revenues from 300-350 foot cantilever jackups increased $28.5 million
(43.6%) because of a 32.2% increase in average dayrates, excluding the Key
Gibraltar, which provided $21.2 million in increased revenues. The remaining
$7.3 million incremental revenue was primarily due to the reclassification of
the Key Gibraltar from other marine rigs in January 1997 following extensive
upgrade. Revenues from 200-250 foot jackup rigs increased $23.4 million (31.8%)
primarily due to a 33.5% increase in average dayrates. Revenues from other
marine rigs increased $6.4 million due to a 69.4% increase in average dayrates,
which was primarily attributable to the North Sea platform rig working in
operating mode
26
<PAGE> 29
approximately seven months more in 1997 than 1996 and increased dayrates on the
lake barge working in Venezuela on a new contract, along with a 39.5% increase
in utilization. Revenues from land rigs increased by $11.3 million (12.3%).
Three new rigs were deployed in 1997, two for work in the Middle East and one in
South America, increasing revenues by $1.9 million. The remaining increase of
$9.4 million was primarily due to a 6.7% increase in dayrates earned by rigs in
service at June 30, 1996. Revenues from drilling related services decreased by
$14.7 million (14.4%) primarily because of a $23.6 million (83.2%) decrease in
project management revenues and a $7.9 million (21.9%) decrease in incentive
drilling contract revenues, partially offset by a $16.8 million (45.1%) increase
in revenues from third party rig operations. Revenues from drilling project
management services decreased with the completion of a contract awarded in late
1995 pursuant to which the Company extensively upgraded a third party
semisubmersible in the Caspian Sea offshore Azerbaijan and the completion of a
platform rig construction project in the North Sea. Incentive drilling revenues
decreased because of a reduction in the number of contracts containing incentive
based provisions primarily in the North Sea. Revenues from third party rig
operations increased primarily due to the operation of a third party
semisubmersible in the Caspian Sea offshore Azerbaijan and increased activity in
the North Sea.
Operating costs. Total operating costs increased $31.2 million (10.1%) due
principally to increased costs related to the operations of the Company's marine
fleet and land rigs, partially offset by lower expenses for drilling related
services. The increases in operating costs related to the Company's heavy duty
harsh environment jackup rigs ($4.7 million or 11.6%) resulted primarily from
increased costs of preparing the Monarch and the Monitor for new contracts in
the North Sea. Semisubmersibles operating costs increased $6.0 million (19.3%)
primarily due to an increase in the utilization of the Aleutian Key in West
Africa in excess of 100% compared with 1996 and higher Aleutian Key maintenance
costs. Increased costs of $9.8 million (25.0%) for the 300-350 foot cantilever
jackup rigs were primarily due to increased costs associated with the
Parameswara's and Compact Driller's deployment to and operations in Australia
and West Africa, respectively, and operation of the Key Gibraltar in Malaysia
following its extensive upgrade and reclassification to the 300-350 foot
cantilever class of rigs. The $5.6 million (10.4%) increase in costs associated
with 200-250 foot jackup rigs was primarily a result of extensive maintenance
and upgrades undertaken on the Key Gibraltar ($7.3 million) while it was being
converted to a cantilever rig, partially offset by reduced costs on rigs working
in the Middle East. The increase of $3.6 million (109.3%) in other marine rig
costs was primarily attributable to a 39.5% increase in utilization and
increased days in operating, rather than idle, mode for the North Sea platform
rig. Operating costs associated with land rigs increased $10.0 million (15.7%),
primarily due to the deployment of three new rigs, two in the Middle East and
one in South America, full year operations of two rigs deployed in 1996 and
increased costs for rigs working in South America. The decrease of $14.4 million
(19.0%) in operating costs associated with drilling related services resulted
from lower project management services expense of $19.3 million (100.0%) and
reduced incentive drilling expense of $2.8 million (10.6%), partially offset by
increased costs from third party rig operations of $7.7 million (25.0%). The
reduction in project management services expense was due to the completion of a
contract to construct a third party platform drilling rig for use in the North
Sea during the first quarter of fiscal year 1997 and from completion in
September 1996 of the extensive upgrade of a third party semisubmersible for use
in the Caspian Sea offshore Azerbaijan. Third party rig operations costs
increased due to the commencement of a contract to operate the same third party
semisubmersible in the Caspian Sea for approximately one year.
General and administrative. General and administrative expense was
effectively flat showing a modest decrease of $0.2 million (1.4%) from the
previous year.
Depreciation and amortization. Depreciation and amortization expense
decreased $33.8 million (43.8%) for the year ended June 30, 1997 as compared
with the same period in the prior year. During 1996, the Company's management
undertook engineering and economic studies to evaluate the economic useful lives
of its drilling rigs. The study results indicated that the estimated useful
lives should be extended from 18 to 30 years for marine rigs and from 12 to 16
years for land rigs. The change in accounting estimate was applied effective
July 1, 1996, with the consequence of reduced depreciation expense and increased
operating income
27
<PAGE> 30
of approximately $34.5 million for fiscal year 1997. See Note 3 of the Notes to
Consolidated Financial Statements.
Other income (expense), net. Total other income (expense), net decreased
$2.4 million for the year ended June 30, 1997. Investment income, net of
interest expense, decreased $4.0 million during the year ended June 30, 1997 due
to the sale of marketable securities during 1996, the proceeds of which were
used to acquire a rig previously operated under capital lease obligation.
Foreign exchange gains increased $2.7 million for the year ended June 30, 1997
primarily resulting from favorable movements of the dollar in relation to the
pound sterling. The annual costs related to services provided under the
provisions of the Intercompany Agreement was $1.1 million for the year ended
June 30, 1997. See "Item 13. Interest of Management in Certain
Transactions -- Related Party Agreements."
Provision for taxes on income. The provision for taxes on income increased
by $5.4 million, primarily due to significantly increased earnings in the U.K.,
Egypt, Venezuela and West Africa, partially offset by a reduction in the
provision for taxes in the U.S. The Company's effective tax rate decreased to
11.5% from 20.4% for the fiscal year ended June 30, 1996 primarily because a
substantial portion of the Company's pre-tax income was either not subject to
taxation or was subject to taxation at reduced rates. See Note 5 of Notes to
Consolidated Financial Statements.
Net income. Net income for the year ended June 30, 1997 increased $102.9
million (166.0%) to $164.9 million as compared to $62.0 million for the same
period in the prior year. This increase resulted primarily from the increase of
$107.7 million in the Company's operating revenues, $33.8 million lower
depreciation expense and higher other income (expense), net of $1.6 million,
partially offset by increased operating expense of $31.2 million, an increased
provision for income taxes of $5.4 million and lower net investment income and
interest expense of $4.0 million.
YEARS ENDED JUNE 30, 1996 AND 1995
Operating revenues. Total operating revenues increased $4.6 million (1.0%)
principally because of increased revenues from heavy duty harsh environment
jackups, semisubmersibles and 300-350 foot cantilever jackups, partly offset by
lower utilization of 200-250 foot jackups and other marine rigs and reduced
revenue from land drilling and drilling related services. Revenues from the
Company's heavy duty harsh environment jackup rig fleet increased $12.7 million
(15.8%) principally because of a 16.0% increase in average dayrates for high
quality equipment in the North Sea which increased revenues $12.8 million.
Following relocation in November 1995 of the Monitor from Australia at the
conclusion of a contract, all of the Company's heavy duty harsh environment
jackup rigs were operating in the North Sea. Operating revenues for the
Company's three semisubmersibles increased $5.8 million (18.2%) because of a
39.3% increase in average dayrates, which increased revenues $12.5 million,
partially offset by a 15.2% decrease in utilization which decreased revenues
$6.7 million. The decrease in utilization resulted primarily from idle time
incurred by the Aleutian Key in preparation for mobilizing to a new contract in
Equatorial Guinea. Revenues from 300-350 foot cantilever jackups increased $6.3
million (10.8%) because of a 5.7% increase in average dayrates providing $3.3
million in increased revenues, which was primarily attributable to operations in
North Africa. The remaining $3.0 million increase in revenues resulted from an
increase in utilization from 91.5% to 95.7%. Revenues from 200-250 foot jackup
rigs decreased $1.7 million (2.3%) primarily due to 3.6% lower utilization.
Other marine rig revenues decreased $7.0 million (60.0%) primarily due to the
retirement of an inland barge in West Africa in the third quarter of 1995 with
no replacement revenues ($4.5 million) in 1996 and lower utilization ($1.5
million) of a lake barge in South America. Revenues from land rigs decreased by
$1.0 million (1.1%) principally because of reduced activity ($6.1 million) in
the Middle East, primarily Kuwait, partially offset by the deployment of one
newly acquired rig in North Africa and one newly acquired rig in South America.
Revenues from drilling related services decreased by $11.5 million (10.1%)
primarily because of a $13.0 million (26.6%) decrease in incentive drilling
contract revenues in the North Sea, North Africa and the Middle East, partially
offset by a $4.6 million (19.2%) increase in project management revenues.
Incentive drilling revenues decreased because of a reduction in the number of
turnkey contracts and contracts containing incentive based provisions. Revenues
from drilling project management services increased primarily because of
recognition of a full year impact applicable to a contract awarded in late 1995
pursuant to which the
28
<PAGE> 31
Company extensively upgraded a third party semisubmersible in the Caspian Sea
offshore Azerbaijan. Revenues from third party rig operations decreased $3.0
million (7.4%) primarily due to reductions in the North Sea and the Middle East,
partially offset by increased activity in South America.
Operating costs. Total operating costs decreased $11.8 million (3.7%) due
principally to decreases in operating costs related to drilling related services
contracts and other marine rigs, partially offset by increases in the operating
costs of the Company's heavy duty harsh environment jackups and
semisubmersibles. Operating costs related to the Company's heavy duty harsh
environment jackup rigs increased $2.6 million (6.9%) primarily due to increased
expenses associated with the Magellan in preparing the rig for skid-off work on
a new contract. Operating expenses for the semisubmersible fleet increased $3.6
million (13.0%) primarily due to increased operating and maintenance expenses
incurred by units operating in the U.S. Gulf of Mexico and West Africa.
Operating expenses for other marine rigs decreased $4.6 million (58.7%)
primarily due to the third quarter 1995 retirement of an inland barge in West
Africa and lower utilization of a lake barge in South America. Operating costs
associated with land rigs increased by $1.3 million (2.1%), primarily resulting
from the deployment of one additional rig for work in South America and one in
North Africa, partially offset by reduced operating costs in the Middle East
attributable to reduced operations in Kuwait. Drilling related services costs
decreased by $14.3 million (15.9%) due to fewer drilling contracts containing
incentive based features in the North Sea and North Africa ($11.9 million) and
$4.6 million in decreased costs related to project management services. This
decrease in project management services costs resulted primarily from an $8.4
million decrease in costs associated with the construction of a third party
drilling rig for a North Sea client, partially offset by a $3.8 million increase
in costs associated with the upgrade of a third party semisubmersible rig for
use in the Caspian Sea offshore Azerbaijan. Costs related to third party rig
operations increased by $2.2 million, mainly due to increased activity in South
America, partially offset by decreases in the North Sea.
General and administrative. General and administrative expense increased
$0.9 million (5.8%) due primarily to increased awards under the Company's
performance based management incentive compensation program.
Depreciation and amortization. 1996 depreciation and amortization expense
decreased $9.8 million (11.3%) due to certain of the Company's assets becoming
fully depreciated during 1995.
Other income (expense), net. Total other income (expense), net increased
$3.9 million for the year ended June 30, 1996. Investment income, net of
interest expense, increased $7.1 million due to the sale of marketable
securities at a gain during 1996, the proceeds of which were used to purchase a
rig previously operated under a capital lease obligation and for distributions
to Holdings. The one remaining obligation under capital lease for the Company's
marine rigs was eliminated during 1996. Foreign exchange losses increased by
$3.2 million primarily due to unfavorable movements of the dollar in relation to
the pound sterling and the Nigerian naira.
Provision for taxes on income. The provision for taxes on income increased
$10.9 million in 1996, primarily due to an increase in U.K. taxes and U.S.
withholding tax obligations related to cross-border intercompany debt which was
repaid, partially offset by reduced operations in Kuwait and Egypt. The
Company's consolidated effective tax rate increased to 20.4% for the year ended
June 30, 1996 from 10.1% for the year ended June 30, 1995, primarily due to a
reduction in the benefit from net operating loss carryforwards in the U.K.,
partially offset by the increase in the portion of the Company's pre-tax income
that was either not subject to taxation or was subject to taxation at reduced
rates. See Note 5 of Notes to Consolidated Financial Statements.
Net income. Net income for the year ended June 30, 1996 increased $17.7
million (39.9%) to $62.0 million as compared to $44.3 million for the prior
year. This increase resulted primarily from an increase of $4.6 million in the
Company's operating revenues, a decrease of $11.8 million in operating expenses,
a decrease of $9.8 million in depreciation expense and an increase of $3.9
million in other income (expense), net, partially offset by an increase of $10.9
million in provision for taxes on income.
29
<PAGE> 32
LIQUIDITY AND CAPITAL RESOURCES
Net cash provided by operating activities was $164.7 million, $74.1
million, $207.2 million, $113.1 million and $131.7 million for the six months
ended December 31, 1997 and 1996 and fiscal years ended June 30, 1997, 1996 and
1995, respectively. The changes in cash flows from operations were primarily
attributable to changes in income before non-cash charges, partially offset by
changes in cash used for working capital. Investing activities used cash of
$131.4 million, $39.0 million, $143.2 million and $14.6 million for the six
months ended December 31, 1997 and 1996 and fiscal years ended June 30, 1997 and
1995, respectively, and provided cash of $5.0 million in the fiscal year ended
June 30, 1996. Cash used in investing activities increased $92.5 million in the
six months ended December 31, 1997, primarily due to increased capital spending
of $82.6 million and increased advance payments related to construction of
drilling rigs of $23.1 million, partially offset by increased sales, purchases
and maturities of marketable securities of $13.5 million. Capital expenditures
totaled $127.1 million, $44.5 million, $146.6 million, $64.8 million and $36.4
million for the six months ended December 31, 1997 and 1996 and fiscal years
ended June 30, 1997, 1996 and 1995, respectively, principally related to rig
expansion, upgrades and modernization. Increased capital spending resulted
primarily from expansion spending for progress payments on the heavy duty harsh
environment jackup rig Galaxy II, partially offset by slightly decreased
maintenance and provisional capital expenditures. Cash used in financing
activities was $3.7 million, $3.8 million, $66.9 million, $108.4 million and
$98.4 million for the six months ended December 31, 1997 and 1996 and fiscal
years ended June 30, 1997, 1996 and 1995, respectively, consisting principally
of repayments of capital lease obligations, distributions to Holdings and
dividends paid. Cash used in financing activities for the six months ended
December 31, 1997 was essentially flat with the corresponding period of the
prior year.
The Company expects to spend approximately $384 million during the year
ending December 31, 1998. Capital spending to meet contractual obligations for
customers and for rig upgrade, modernization and enhancement projects is
estimated to require approximately $64 million and represent numerous individual
transactions spread over the course of the year. Progress payments on the two
new heavy duty harsh environment jackup rigs presently under construction are
estimated to require approximately $180 million. The Company believes it has
minimal exposure to significant cost increases in constructing either rig as the
construction contracts with the shipyard are fixed price arrangements. Further,
the Company has to date been, and expects through the completion of these rig
construction projects to be, successful in purchasing the Company provided
drilling equipment at price and delivery terms within the Company's initial
project estimates. The Company currently has four high specification land rigs
under construction for contracts in South America. Current estimates indicate
approximately $50 million will be needed to complete these rigs for initial work
beginning during the third and fourth quarters of 1998. In addition, the Company
had identified $40 million and $50 million, respectively, as amounts intended
for use in constructing a new high specification heavy duty jackup rig and the
acquisition of two additional 3,000 horsepower land rigs. It is expected that
the entire 1998 capital program will be funded from internally generated funds.
Future capital spending, particularly rig fleet additions, is subject to the
Company's prospects for securing appropriate drilling contract opportunities and
the availability of suitable rigs, rig components, construction facilities and
supplies.
From time to time, the Company reviews opportunities for rig acquisition,
construction or upgrade. Once a capital project is undertaken by the Company,
factors outside the Company's control, such as changes in market demand, may
alter the project economics and the Company may be unable to fully recoup the
cost of such expenditures through future drilling contracts. Should current
plans for rig acquisition, construction or upgrade not be completed, the Company
will not have those rigs available to compete in its markets.
On March 25, 1998, the Company's Board of Directors declared a quarterly
dividend of $0.0325 per Ordinary Share payable on April 15, 1998 to holders of
record at the close of business March 31, 1998. The Company's current dividend
policy contemplates payment of future quarterly dividends of $0.0325 per
Ordinary Share.
The Company's principal source of funds has been cash flow from operations.
The Company believes available cash resources and cash flows from operations
will be sufficient to meet its capital requirements during 1998.
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Subject to the approval of the final terms by the Executive Committee of
the Board of Directors, the Board of Directors has authorized the Company to
obtain a revolving line of credit up to $50 million. However, the Company
currently does not have any commitments or agreements relating to a line of
credit, and there can be no assurance that the Company will obtain a revolving
line of credit on terms satisfactory to the Company.
INDUSTRY RISK
The Company is subject to many risks which could impair liquidity and
operating results, because of decreased revenues, increased expenses or both.
Should the industry engage in a more extensive rig building program, the
resulting increase in rig supply could cause a rapid deterioration of the market
for the Company's rigs. Furthermore, the contract drilling industry is
influenced by customer drilling budgets and expenditures, oil and natural gas
pricing, consumption and demand, energy prices and policies and is a highly
competitive and cyclical industry. The industry may encounter periods of rapid
downturn which result in substantially reduced dayrates and low utilization. A
reduction in industry utilization could idle some of the Company's drilling
rigs, in which event the Company must bear the idle rig expenses without any
offsetting revenue. Any of these events could have a materially adverse effect
on the Company's revenues, gross margins and net income and the Company's
liquidity in future periods.
CURRENCY RISK AND INFLATION
The Company conducts material business operations in foreign currency
environments, including the U.K., Venezuela, Indonesia and Egypt. The Company
generally attempts to minimize its currency exchange risk by seeking
international contracts payable in local currency in amounts equal to the
Company's estimated operating costs payable in local currency and in dollars for
the balance of the contract. Because of this strategy, the Company has minimized
its net asset or liability positions denominated in local currencies and has not
experienced significant gains or losses associated with changes in currency
exchange rates. Accordingly, the Company has not historically entered into
financial hedging arrangements to manage risks relating to fluctuations in
currency exchange rates. However, the Company may enter into such contracts in
the future in the event that the Company assumes significant foreign currency
risks.
Although inflation has not had a significant impact on the Company's
results of operations during the past several years, the Company recently has
experienced significant increases in the cost of rig related equipment and spare
parts. The Company's financial results could be negatively affected in the
future by these or similar cost increases.
CREDIT RISK
The Company's customers consist primarily of major international, state
owned and large independent oil companies and their affiliates. The Company has
not incurred any charges for credit losses during the last five years. There is
no assurance that in the future such charges will not occur. Such charges may
adversely affect the Company's profitability.
OTHER
Operational risks and hazards may result in extensive damage to or total
loss of drilling rigs, with associated personal injuries and loss of life,
pollution, well loss, well control expenses and/or wreck removal or other
requirements. Such losses, liabilities or obligations may be uninsured or
underinsured. In the event of a major incident or incidents resulting from
operational risks and hazards, the Company will sustain a loss of revenue by
reason of the rig loss or damage and may be subject to extraordinary expenses in
respect of uninsured or underinsured losses, liabilities or obligations.
The Company's worldwide operations are subject to numerous international,
U.S., state and local environmental laws and regulations that relate directly or
indirectly to its operations, including certain regulations controlling the
discharge of materials into the environment, requiring removal and clean-up
under certain circumstances, or otherwise relating to the protection of the
environment. Laws and regulations
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protecting the environment have become increasingly stringent in recent years
and may in certain circumstances impose "strict liability" and render a company
liable for environmental damage without regard to negligence or fault on the
part of such company. Such laws and regulations may expose the Company to
liability for the conduct of or conditions caused by others, or for acts of the
Company that were in compliance with all applicable laws at the time such acts
were performed. See "Item 1. Description of Business -- Business Considerations
and Risk Factors -- Environmental and Regulatory Risks."
The Company's liquidity also may be adversely impacted by reason of war,
political turmoil, revolution, insurrection or similar events which could, inter
alia, result in damage to or loss of the Company's rigs, either physically or by
reason of nationalization, expropriation or deprivation of use, or could impair
the concessionary rights of the Company's customers, thus jeopardizing the
Company's drilling contracts. The Company does not normally insure against these
risks, and such events could result in an actual or constructive loss of
substantial assets and the associated loss of revenues and/or receivables.
IMPACT OF YEAR 2000
The year 2000 issue is the result of computer microprocessors and
application software being written using two digits rather than four to define
the applicable year. Any of the Company's microprocessors or application
software that are time-sensitive may recognize a date of "00" as the year 1900
rather than the year 2000. This could result in a system failure or
miscalculations causing disruptions of operations, including, among other
things, a temporary inability to operate machinery, process transactions, send
invoices or otherwise engage in normal business activities.
The Company has had a preliminary program in place for approximately one
year involving examination and identification of potential disruptions to the
Company's activity due to year 2000 date recognition concerns with its
microprocessors. The activity has been conducted independently by the users of
the Company's business systems and the mechanical equipment groups. In January
1998, an individual with broad operations and management experience was named to
the position of "Manager -- Year 2000 Project" and has been charged with
immediate coordination of all Company-wide efforts to effect remedial action as
required on an immediate basis. Additional risk areas, if any, are to be
identified and aggressively addressed to determine whether the Company and its
customers are reasonably protected against operational and business systems
interruption concerns.
The Company currently believes that all significant accounting and business
systems have been evaluated and appropriate remedial action identified. Specific
remedial plans were established and, in most cases, action was initiated at that
time. The Company has five primary business systems that require addressing. A
software vendor is in the process of providing year 2000 compliant software for
two applications. One system is a new internally developed system that was
developed in compliance with year 2000 considerations. Specific remedial scope
has been established to renovate the remaining two software applications with
the intention of being compliant in advance of January 1, 1999. Additionally,
the Company, for reasons not related to year 2000 issues, is moving to a Windows
NT server environment for worldwide application as an unrelated modernization of
its computer technology. The present estimated cost of the actions described
above range from $4 million to $6 million, approximately half of which is
associated with replacing mainframe legacy computer systems with Windows NT
servers and will be capitalized.
Evaluations of vendors and suppliers of equipment and materials has been
initiated to determine whether they are taking necessary action to ensure that
materials and equipment purchased by the Company is year 2000 compliant.
Further, various evaluations have been underway at the field operations level to
identify risk areas including a detailed review at the Company's largest
operating location. To date, results of these location specific examinations
indicate minimal concerns; however, all operating locations have not been
examined. All locations will be reviewed during 1998. At this time the Company
cannot determine whether the results of these reviews will identify significant
matters to address before they have a material impact on its operations.
Accordingly, the Company cannot assess at this time whether future actions are
required, the extent to which they can be completed timely and whether they will
have a material impact on future operations.
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ITEM 9A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
Not applicable.
ITEM 10. DIRECTORS AND OFFICERS OF REGISTRANT.
The Board of Directors of the Company currently has nine members. The
Company's Articles divide the Board of Directors into three classes having
staggered terms of three years each, with Classes I, II and III having initial
terms expiring at the annual general meeting of shareholders in 1998, 1999 and
2000, respectively. The Articles also require the number of Directors to be not
less than nine nor more than 15 and provide that the Board is to determine, from
time to time, the number of Directors to be on the Board. Officers are elected
by the Board of Directors for one year terms of office expiring at the next
annual meeting of shareholders. Information with respect to the current
Directors and executive officers of the Company is set forth below.
DIRECTORS AND EXECUTIVE OFFICERS
The following is a list of the Directors and executive officers of the
Company as of February 28, 1998.
<TABLE>
<CAPTION>
NAME AGE POSITION
---- --- --------
<S> <C> <C>
Gordon M. Anderson......................... 65 Chairman of the Board and Class I Director
C. Stedman Garber, Jr...................... 54 President, Chief Executive Officer and
Class III Director
Abdulmalik Mohammed Al-Gharabally.......... 54 Class I Director
Abdullah Hamad Al-Roumi.................... 48 Class I Director
Khalid Yousef Al-Fulaij.................... 44 Class II Director
Ferdinand Anton Berger..................... 59 Class II Director
Nader Hamad Sultan......................... 49 Class II Director
Sami Fahed Al-Rushaid...................... 43 Class III Director
Robert E. Wycoff........................... 67 Class III Director
Donald G. Barber........................... 63 Senior Vice President and Chief Financial
Officer
Gordon W. McCullough....................... 63 Senior Vice President, Drilling Operations
Roger B. Hunt.............................. 48 Senior Vice President, Commercial Manager
Ali Awad................................... 57 Vice President and Area Manager
James A. Blue.............................. 52 Vice President and Regional Manager
Seals M. McCarty........................... 51 Vice President and Controller
Cary A. Moomjian, Jr....................... 50 Vice President, General Counsel and
Secretary
Tom L. Seeliger............................ 54 Vice President and Area Manager
C. Miles Sheldon........................... 49 Vice President and Area Manager
</TABLE>
Gordon M. Anderson has served as a Director of the Company since 1969. Mr.
Anderson was appointed President and Chief Executive Officer in 1991 and became
Chairman of the Board of Directors in 1993. Mr. Anderson has worked with the
Company since June 1954. Following several international assignments, he was
appointed President of Santa Fe Drilling Company in 1972. Mr. Anderson retired
as Chief Executive Officer in December 1997 and currently serves as a
non-employee Director and Chairman of the Board. Mr. Anderson also serves as a
Director of the American Petroleum Institute and as a Trustee of the American
University in Cairo.
C. Stedman Garber, Jr. has served as a Director of the Company since 1989.
Mr. Garber was employed by Getty Oil Company between 1977 and 1984. Mr. Garber
joined the Company in 1984 as Vice President of Planning and Acquisition and in
1989 was appointed President of Santa Fe Minerals, Inc., a former subsidiary of
the Company. Mr. Garber was named Executive Vice President and Chief Operating
Officer of the Company in 1991, was appointed President and Chief Operating
Officer in December 1995 and was appointed Chief Executive Officer effective
January 1, 1998.
Abdulmalik Mohammed Al-Gharabally has served as a Director of the Company
since 1982. Mr. Al-Gharabally has been Adviser to Kuwait Petroleum Corporation
since 1992. Previously he was
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Managing Director, Exploration and Production, of KPC and Chairman and Managing
Director of Kuwait Oil Company, K.S.C. Mr. Al-Gharabally also serves as a
Director of Holdings and as Chairman of Kuwait Santa Fe for Engineering and
Petroleum Projects Company (K.S.C.).
Abdullah Hamad Al-Roumi has served as a Director of the Company since
January 1995. Since 1992 he has served as Chairman and Managing Director of
Kuwait Oil Tanker Company, a subsidiary of KPC. Mr. Al-Roumi also serves as a
Director of KPC, Holdings and the U.K. P&I Club.
Khalid Yousef Al-Fulaij has served as a Director of the Company since
January 1995. Since 1992 he has served as Chairman and Managing Director of
Kuwait Oil Company, K.S.C., a subsidiary of KPC. Mr. Al-Fulaij also serves as a
Director of KPC and Holdings.
Ferdinand A. Berger has served as a Director of the Company since September
1997. Mr. Berger retired from the Shell Group of Companies at the end of 1996,
having served in various management positions in South America, the Middle East
and Europe since 1965. He was appointed Senior Vice President of Shell
International Trading Company in 1987 and served as a Director of Shell
International Petroleum Company Limited, with responsibility for overall Shell
Group activities in the Middle East, Africa and South Asia from 1992 until his
retirement. He is also a Director of Xpronet Inc., a privately owned oil and gas
exploration and production company.
Nader Hamad Sultan has served as a Director of the Company since January
1995. Since 1993, he has served as Deputy Chairman and Managing Director,
Planning and International Operations, of KPC. Mr. Sultan also serves as a
Director of KPC and Holdings.
Sami Fahed Al-Rushaid has served as a Director of the Company since
September 1997. Mr. Al-Rushaid joined the Kuwait National Petroleum Company
("KNPC"), a subsidiary of KPC, in 1978. He held various positions in the KNPC
Corporate Planning Department until 1995, when he assumed his current position
as KNPC's Executive Assistant Managing Director of Planning and Finance. Mr.
Al-Rushaid also is a Director of Petrochemical Industries Co., a KPC subsidiary.
Mr. Al-Rushaid also serves as a Director of Holdings.
Robert E. Wycoff has served as a Director of the Company since September
1997. Mr. Wycoff retired from the Atlantic Richfield Company ("ARCO") in 1993,
having served with ARCO since 1953. After holding various engineering and
management positions, he was named Vice President and Resident Manager of ARCO's
Alaska Region in 1973. Mr. Wycoff served as a Director, President and Chief
Operations Officer of ARCO from 1986 until his retirement. He is also a director
of MagneTek, Inc., a publicly traded company engaged in electronic equipment and
controls.
Donald G. Barber joined the Company in 1985 as Senior Vice President of
Santa Fe Minerals, Inc., a former subsidiary of the Company, and has served as
Senior Vice President and Chief Financial Officer of the Company since December
1986. Mr. Barber previously served as Chief Financial Officer of Aminoil, Inc.
and in senior financial positions with Exxon U.S.A.
Gordon W. McCullough joined the Company in 1962. He has worked in
progressively more senior management positions, primarily internationally,
including assignments in the United Kingdom, Holland, Norway, Nigeria, Brazil,
Libya and Angola. In 1982, Mr. McCullough was appointed Managing Director of the
Company's North Sea operations. In January 1994, Mr. McCullough was named the
Company's Senior Vice President, Drilling Operations.
Roger B. Hunt joined the Company in 1970. During the period 1977 through
1982, he was assigned to Venezuela as Assistant Zone Manager. In 1983, he was
named Vice President and Manager of International Sales and in 1988 was assigned
regional operations responsibilities as Vice President and Regional Manager for
Asia, Australia, Venezuela, Azerbaijan, West Africa and the Gulf of Mexico. He
assumed his current responsibilities as Senior Vice President, Commercial
Manager, during September 1997.
Ali Awad joined the Company in 1974 following a distinguished career with
major oil companies operating locally in Egypt. He has held several managerial
positions in Egypt, including Zone Manager from
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<PAGE> 37
1979 to 1993. In 1993, he was promoted to his current position of Vice President
and Area Manager responsible for all offshore and land operations in Egypt as
well as other operations in the Mediterranean area.
James A. Blue joined the Company in 1965. He initially served in various
assignments in England, Egypt, Libya, Scotland and Venezuela. He was named Vice
President and Regional Operations Manager in 1989. In 1997, he assumed his
current position of Vice President and Regional Manager with responsibility for
operations in Azerbaijan, the Gulf of Mexico, Venezuela and West Africa.
Seals M. McCarty joined the Company in 1985 concurrently with the purchase
of Keydril Company from Gulf/Chevron. He had served as Vice President of Finance
for Keydril since 1982. Mr. McCarty has held various financial positions with
the Company including his present position as Vice President and Controller.
Cary A. Moomjian, Jr. joined the Company in 1976. After two years as
Corporate Marine Counsel, Mr. Moomjian served as Santa Fe Drilling Company's
Senior Counsel and then Vice President, General Counsel. In 1983, Mr. Moomjian
was named Vice President, Contracts for Santa Fe Drilling Company. In January
1994, Mr. Moomjian was named Vice President, General Counsel and Secretary.
Tom L. Seeliger joined the Company in 1965. He has worked in progressively
more senior management positions, primarily internationally, including
assignments in Nigeria, the North Sea, Libya, Argentina, Trinidad, Venezuela and
London. In 1993, Mr. Seeliger assumed his current position as Vice President and
Area Manager for North Sea operations.
C. Miles Sheldon joined the Company in 1977 as Business Development Manager
for offshore construction activities. In 1981, after assignments in Saudi Arabia
and Kuwait in a marketing capacity, he was named General Manager for the
Company's operations in Kuwait and in 1984 was promoted to Vice President. In
1993, Mr. Sheldon was assigned regional operations responsibilities as Vice
President and Area Manager for Kuwait, Saudi Arabia, Oman and Qatar.
ITEM 11. COMPENSATION OF DIRECTORS AND OFFICERS.
COMPENSATION OF DIRECTORS AND OFFICERS
For the calendar year ended December 31, 1997, the aggregate remuneration
paid by the Company (which includes salary and other cash payments under the
Company's benefit plans and policies) to all Directors and executive officers of
the Company as a group (18 persons) for services in all capacities was
$9,291,865.
The Company and Gordon M. Anderson, a Director of the Company, entered into
a Consulting Agreement dated December 10, 1997 pursuant to which Mr. Anderson
receives certain compensation. See "Item 13. Interest of Management in Certain
Transactions -- Consulting Agreement."
DIRECTOR FEES AND STOCK OPTIONS
Effective July 1, 1997, the Board adopted a policy whereby each
non-employee Director is paid an annual retainer fee of $20,000 plus meeting
fees of $2,000 for each Board and committee meeting (other than telephonic
meetings) attended by that Director. Each non-employee Director also is paid a
meeting fee of $500 for any Board or committee telephonic meeting of one hour or
longer and an additional $1,000 for each Board meeting such Director attends
outside his or her country of residence. Each non-employee Director who serves
as a committee chairman receives an additional meeting fee of $1,000. The
Company also reimburses its Directors for travel, lodging and related expenses
they may incur attending Board and committee meetings. The Company has also
adopted a stock option plan for certain non-employee Directors. See "-- Long
Term Incentive Plans -- 1997 Non-Employee Director Stock Option Plan."
INVESTMENT SAVINGS AND PROFIT SHARING (401(k)) PLAN
The Company maintains an Investment Savings and Profit Sharing Plan, a
defined contribution 401(k) plan that allows dollar payroll employees to make
both pre-tax and after-tax employee contributions. The Company matches these
employee contributions up to a maximum of 5% of a participant's base salary
subject
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<PAGE> 38
to the limitations of eligible salary. Employees are vested in all contributions
made. Additionally, although it has not done so since 1984 and does not
currently expect to do so in the future, the Company has the option to make
additional employer contributions any year out of profits.
ANNUAL INCENTIVE COMPENSATION PLAN
The Company also maintains an Annual Incentive Compensation Plan ("AIP").
The AIP provides for payment of additional compensation to participating
employees, including executive officers, based on individual contributions and
overall performance of the Company and its key operating business units during
the fiscal year. The AIP is administered by the Compensation Committee.
Employees of the Company and its subsidiaries eligible for awards under the AIP
are executive officers, officers and other key management personnel of the
Company and its subsidiaries, whose performance, in the judgment of the
Compensation Committee, can have a significant effect on the success of the
Company. During the term of the AIP, an aggregate of 286,250 Ordinary Shares
will be available for awards granted wholly or partly in Ordinary Shares under
the AIP.
In general, the Compensation Committee will establish a target incentive
award for each participant based on performance measures (and performance scales
for the measures) and individual objectives. The maximum target incentive award
shall not exceed 100% of the participant's base salary in effect at the
beginning of the plan year. The current performance measures are cash flow from
operations and cash flow from operations divided by revenue as compared to
certain peer group companies set forth in the AIP. In general, except for
"covered employees," as defined in Section 162(m) of the Internal Revenue Code
of 1986, as amended (the "Code") (relating to deduction limits for compensation
over $1 million), the Compensation Committee has discretion to vary these
measures and the relative weight to assign to the various objectives. With
respect to covered employees, the individual objectives must be capable of
determination by a third party and all of the objectives must be established
during the first 90 days of the plan year.
In the event of a Change in Control (as defined below), (i) if the various
objectives have not yet been determined during the plan year, then the
objectives and participants shall generally be based on the same rules as set
forth in the preceding plan year and (ii) in general, participants are eligible
for full unprorated target incentives for that year.
PENSION PLANS
The Company maintains a tax-qualified pension plan for employees of the
Company and participating subsidiaries who are residing in or are citizens of
the United States and who have completed one year of service, and a "mirror"
non-qualified pension plan for selected non-U.S. management and other employees
of the Company and participating subsidiaries which provides substantially
similar benefits (hereafter referred to collectively as the "Pension Plans"). In
addition, the Company maintains two non-qualified pension plans that provide
certain additional pension benefits.
The Pension Plans provide for monthly retirement benefits upon normal
retirement at age 62 based on the number of credited years of service and the
average of the highest 60 months of salary covered by the Pension Plans. The
Pension Plans permit retirement as early as age 55 with reduced benefits. The
Equity Restoration Plan restores to Pension Plan participants any benefits
otherwise lost as a result of the benefit limitations contained in Section 415
of the Code and limitations contained in Section 401(a)(17) of the Code on the
amount of compensation includable in determining benefits provided by
tax-qualified trusts. The Company's Supplemental Executive Retirement Plan
("SERP") provides additional benefits for a select group of management employees
as a means to attract and retain employees of exceptional ability who are
critical to the Company's success.
For employees who participate only in the Pension Plans and the Company's
Equity Restoration Plan, the annual retirement income benefit is equal to 1.525%
of the participant's average annual base salary in the highest 60 consecutive
months during the final 10 years of service multiplied by years of credited
service, plus 0.475% of this same base salary amount less the participant's
Social Security Covered Compensation (as defined), multiplied by years of
credited service not exceeding 35 years. For employees who also participate in
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<PAGE> 39
the SERP, the benefit so calculated will not be less than 60% of the
participant's average annual salary and bonus in the highest consecutive 36
months during the final five years of service, reduced ratably for service under
15 years.
LONG TERM INCENTIVE PLANS
Performance Unit Plan
On June 28, 1995, the Company adopted the Santa Fe International
Corporation Performance Unit Plan ("Performance Unit Plan") to provide incentive
via performance share units to foster and promote the long-term financial
success of the Company and materially increase the value of the equity interests
of the shareholder.
Each unit awarded under the Performance Unit Plan represents the right to
receive an amount in cash on the date of payout, the amount of which depends
upon the Company's targeted three-year total cash flow from operations and a
return on fixed assets (three-year average of the annual cash flow from
operations divided by fixed assets) compared to a comparative group of peer
companies. The minimum (threshold) is $20 per unit, which is payable if the
Company's cash flow from operations equals 80% of targeted cash flow from
operations and the Company's return on fixed assets equals the 40th percentile
of its peer companies. If the results are less than threshold for any of the two
performance criteria, no awards are earned. The target amount of $100 per unit
is payable if the Company meets targeted total cash flow from operations and
return on cash flow equals the 60th percentile of its peer companies. The
maximum amount of $300 per unit is payable if the Company's cash flow from
operations equals or exceeds 150% of targeted cash flow from operations and
return on cash flow equals or exceeds the 90th percentile of peer companies.
There are 14 persons who participate in the Performance Unit Plan.
The last awards under the Performance Unit Plan were granted in December
1996. No further awards will be made under the Performance Unit Plan. The
Performance Unit Plan will remain in existence until the last performance cycle
has elapsed and payouts, if any, have been made to participants. It is expected
that the Performance Unit Plan will terminate shortly after the results have
been finalized for the third plan year ending June 30, 1999. In the event of a
Change in Control (as defined below) the performance share units granted would
become fully vested.
1997 Long Term Incentive Plan
The Company has adopted the 1997 Long Term Incentive Plan (the "LTIP"),
which is designed to retain key executives and other selected employees by
rewarding them for making major contributions to the success of the Company and
to provide participants with a proprietary interest in the growth and
performance of the Company.
Employees of the Company eligible for awards under the LTIP are executive
officers, other officers and key management personnel selected by the
Compensation Committee (including employees who are Directors), and whose
performance, in the judgment of the Compensation Committee, can have a
significant effect on the success of the Company. As of December 31, 1997, there
were 426 persons who participated in the LTIP. Awards under the LTIP may consist
of the grant of stock options, share appreciation rights, restricted and/or
performance-based share awards and/or restricted and/or performance-based cash
awards, granted singly, in combination or in tandem. The exercise price for
stock options shall not be less than 85% of the fair market value of the stock
on the date of the option grant (100% in the case of incentive stock options).
The Compensation Committee can also award supplemental payments up to the amount
necessary to pay the federal income tax payable with respect to exercise of
non-qualified stock options, share appreciation rights, restricted shares and
performance units. If approved by the Compensation Committee, the Company may
also make loans to participants to purchase shares pursuant to the exercise of
an award. During the term of the LTIP, an aggregate of 5,725,000 Ordinary Shares
will be available for awards granted wholly or partly in Ordinary Shares under
the LTIP. No participant may receive during a fiscal year incentive awards
covering an aggregate of more than 150,000 Ordinary Shares.
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The Compensation Committee is responsible for administration and
interpretation of the LTIP. When a participant's employment with the Company is
terminated, any unexercised, deferred or unpaid awards will be treated as
provided in the specific agreement evidencing the award. If a participant is
involuntarily terminated, other than for "cause" (as defined in the LTIP), or
terminates for "good reason" (as defined in the LTIP) within two years after a
Change in Control (as defined below), all outstanding stock options shall become
vested and immediately exercisable and will remain exercisable until the earlier
of the expiration of their term or the first anniversary of the termination of
employment, all shares of restricted stock will immediately cease to be
forfeitable and all conditions relating to realization of any other stock-based
or non-stock award will immediately terminate. In addition, upon a Change in
Control (as defined below), the Company will have the right to cash out all
incentive awards (and all non-vested awards will vest) based on their fair
market value; for this purpose, their market value will be the average fair
market value per share on each of the five trading days immediately following a
Change in Control or the highest price per share, if any, offered in connection
with a Change in Control, whichever is higher. This cash out is automatic if the
stock of the surviving entity in a Change in Control is not publicly traded.
As of February 28, 1998, the Company had granted options pursuant to the
LTIP to purchase an aggregate of 387,650 Ordinary Shares to all Directors and
executive officers as a group (18 persons). Such options were granted at
exercise prices ranging from $28.50 to $45.00 per Ordinary Share, and expire ten
years from date of grant or earlier. In addition, the Company has granted
restricted share awards for an aggregate of 107,600 Ordinary Shares to all
Directors and executive officers as a group (18 persons).
1997 Non-Employee Director Stock Option Plan
The 1997 Non-Employee Director Stock Option Plan (the "Director Plan") has
been adopted by the Company. The Director Plan is designed to attract and retain
the services of experienced and knowledgeable non-employee Directors and to
provide non-employee Directors with a proprietary interest in the growth and
performance of the Company. Awards under the Director Plan consist of a grant of
stock options. The purchase price for the shares as to which the option is
exercised will be payable in full upon exercise, in cash or, if permitted by the
Compensation Committee, by tender of Ordinary Shares, valued at "fair market
value." During the term of the Director Plan, an aggregate of 286,250 Ordinary
Shares will be available for awards granted wholly or partly in Ordinary Shares.
No option will be granted under the Director Plan after 10 years following
consummation of the Company's initial public offering of Ordinary Shares in June
1997 (the "Offering"). The Compensation Committee is responsible for
administration and interpretation of the Director Plan.
As of February 28, 1998, the Company had granted options to purchase an
aggregate of 28,000 Ordinary Shares to seven non-employee Directors who
participated in the Director Plan. Such options were granted at exercise prices
ranging from $28.50 to $45.50 per Ordinary Share. Any new non-employee Director
will be granted a one-time award of a right to purchase 4,000 Ordinary Shares
upon their election to the Board at the fair market stock price/value on the
date of their election. Each non-employee Director who continues in office
immediately following the Annual General Shareholders Meeting in any year
(commencing in 1998) will automatically be granted an option to acquire 2,000
shares of Ordinary Shares. The Board may increase the number of options granted,
provided that a non-employee Director cannot receive more than 10,000 options in
any year. The price of shares that may be purchased upon exercise of an option
is the fair market value of the Ordinary Shares on the date of the grant.
Options granted pursuant to the Director Plan are exercisable in installments of
33 1/3% upon each anniversary of the date of grant. The term of each option is
for a period not exceeding 10 years from the date of grant.
In the event of a Change in Control of the Company (as defined below), all
outstanding stock options will become vested and immediately exercisable and
will remain exercisable until the earlier of the expiration of their term or the
first anniversary of the Change in Control. In addition, the Company may cash
out options upon a Change in Control; these provisions are substantially the
same as set forth in the LTIP.
38
<PAGE> 41
1997 Employee Share Purchase Plan
The Company has adopted the 1997 Employee Share Purchase Plan (the "Share
Purchase Plan"), which is designed to furnish eligible employees of the Company
and designated subsidiaries of the Company an incentive to advance the best
interests of the Company by providing a formal program whereby they may
voluntarily purchase Ordinary Shares of the Company at a favorable price and
upon favorable terms. Generally speaking, all covered employees of a
participating company who are scheduled to work an average of at least 20 hours
per week are eligible to participate in the Plan.
Once a year, participants in the Share Purchase Plan are granted options to
purchase Ordinary Shares with a fair market value equal to the lesser of 10% of
the participant's eligible compensation (as defined in the Share Purchase Plan)
and the amount specified in Section 423(b) of the Code (currently, $25,000). The
exercise price of the options is 85% of the fair market value of the Ordinary
Shares on the date of grant or the date of exercise, whichever is less. Options
granted under the Share Purchase Plan are exercisable on the date one year after
the date of grant. Generally speaking, participants pay option exercise prices
through payroll deductions. An aggregate of 572,500 Ordinary Shares are
available for grants of options under the Share Purchase Plan. The Share
Purchase Plan policy is administered by the Compensation Committee, which has
approved its implementation effective January 1, 1998.
1997 Employee Severance Protection Plan
The Company maintains the 1997 Employee Severance Protection Plan (the
"Severance Protection Plan") to retain the services of its employees in the
event of an unsolicited takeover of the Company or in the event of a threat of a
Change in Control of the Company. The Severance Protection Plan is intended to
ensure the continued dedication and efforts of the Company's employees in such
events without undue concern for their personal financial and employment
security. The Severance Protection Plan covers all full-time U.S.-based payroll
employees as defined therein. Severance is only payable in the event of a
termination of employment by the Company other than for "cause" or voluntary
termination by the Employee for "good reason," each as defined in the Severance
Protection Plan, within a specified period following a Change in Control. A
participant will also receive severance if the employee is terminated by the
Company without "cause" or for "good reason" at the request or direction of the
third party involved in the Change in Control or otherwise in connection with or
in anticipation of a Change in Control.
DEFINITION OF CHANGE IN CONTROL
A "Change in Control" for all of the Company's benefit plans described
above is generally deemed to occur (a) if any person (as such term is used in
Sections 13(d) and 14(d)(2) of the Securities Exchange Act of 1934, as amended
(the "Exchange Act")) is or becomes the beneficial owner (as defined in Rule
13d-3 under the Exchange Act), directly or indirectly, of securities of the
Company representing 20% or more of the combined voting power of the Company's
then outstanding securities; (b) if, during any period of two consecutive years,
individuals who at the beginning of such period constitute the Board of
Directors of the Company cease for any reason to constitute at least a majority
thereof, unless the election or nomination for the election by the Company's
shareholders of each new Director was approved by a vote of at least two-thirds
of the Directors then still in office who were Directors at the beginning of the
period; or (c) upon consummation of a merger, consolidation or similar event, if
the equity holders of the Company prior to the transaction have beneficial
ownership of less than 50% of the combined voting power of the surviving entity;
(d) upon any sale, disposition or similar transaction of 50% or more of the
assets or earning power of the Company or business operations which generate a
majority of the consolidated revenues; or (e) upon a liquidation of the Company.
ITEM 12. OPTIONS TO PURCHASE SECURITIES FROM REGISTRANT OR SUBSIDIARIES.
See "Item 11. Compensation of Directors and Officers."
39
<PAGE> 42
ITEM 13. INTEREST OF MANAGEMENT IN CERTAIN TRANSACTIONS.
This section describes certain transactions among KPC, Holdings and the
Company that occurred prior to the Company's Offering and certain arrangements
that will be in effect after the Offering. Because the Company is controlled by
KPC, these transactions and arrangements were not the result of arms-length
negotiations. See Note 12 of the Notes to Consolidated Financial Statements.
SPECIAL DISTRIBUTIONS TO KPC
The Company made distributions in respect of the Offering and its contract
drilling operations and its drilling related services in cash or cash
equivalents to Holdings with a net value of $3.8 million, $1,147.6 million,
$50.0 million and $72.5 million during the six months ended December 31, 1996
and the fiscal years ended June 30, 1997, 1996 and 1995, respectively.
CONTRACT DRILLING SERVICES
The Company provides contract drilling and associated services in Kuwait to
the Kuwait Oil Company K.S.C. ("KOC"), a subsidiary of KPC, and also provides
contract drilling services to a partially owned affiliate of the Kuwait Oil
Company in the Kuwait-Saudi Arabia Partitioned Neutral Zone. Such services are
performed pursuant to drilling contracts which contain terms and conditions and
rates of compensation which materially approximate those which are customarily
included in the Company's arms-length contracts of a similar nature. In
connection therewith, KOC provides the Company rent-free use of certain land and
maintenance facilities and has committed to continue providing same, subject to
availability of the maintenance facilities, through the current February 2001
term of the drilling contracts. In relation to its drilling business in Kuwait,
the Company has an agency agreement with a subsidiary of KPC which obligates the
Company to pay an agency fee based upon a percentage of revenues. The Company
believes the terms of this agreement are more favorable than those which could
be obtained with an unrelated third party in an arms-length negotiation, but the
value of such terms is currently immaterial to the Company's results of
operations.
The Company earned revenues from KPC affiliated companies in the ordinary
course of business of $17.3 million, $12.8 million, $25.3 million, $35.9 million
and $53.6 million for the six months ended December 31, 1997 and 1996 and for
the fiscal years ended June 30, 1997, 1996 and 1995, respectively. The Company
paid agency fees to a subsidiary of KPC of $0.2 million, $0.2 million, $0.3
million, $0.4 million and $0.5 million during the six months ended December 31,
1997 and 1996 and for the fiscal years ended June 30, 1997, 1996 and 1995,
respectively. The Company had accounts receivable from KPC affiliated companies
of $5.6 million, $2.3 million, $2.1 million and $3.7 million at December 31,
1997 and 1996 and June 30, 1997 and 1996, respectively.
REORGANIZATION
The reorganization of Holdings and its subsidiaries resulted in the Company
owning all of the drilling assets and direct and indirect subsidiaries of
Holdings and KPC that provide contract drilling and drilling related services.
In connection with the reorganization, the Company made distributions to
Holdings during the three years ended June 30, 1997 comprised principally of
certain subsidiaries which conducted the Company's former non-drilling
operations and services (the "Non-Drilling Subsidiaries") and certain additional
non-drilling assets, including real estate, cash and cash equivalents. The
operations and services formerly conducted by the Non-Drilling Subsidiaries
included oil and natural gas production and exploration activities, pipelaying
and other onshore and offshore heavy construction activities, engineering
activities and geothermal electrical production activities. As part of the
reorganization, Holdings also contributed to the Company assets relating to the
Company's contract drilling operations during the six months ended December 31,
1996 and the fiscal years ended June 30, 1997, 1996 and 1995. These transactions
have been accounted for as a reorganization of entities under common control in
a manner similar to a pooling of interests. See Note 1 of the Notes to
Consolidated Financial Statements.
40
<PAGE> 43
RELATED PARTY AGREEMENTS
The following summary description of the agreements among the Company,
Holdings and KPC and of the Articles is qualified in its entirety by reference
to the forms of Intercompany Agreement and Management Services Agreement and the
Articles filed as exhibits to this Transition Report on Form 20-F.
Intercompany Agreement
In connection with the Offering, the Company, Holdings and KPC have entered
into an Intercompany Agreement (the "Intercompany Agreement"), certain
provisions of which are summarized below. As used herein, "KPC Affiliated Group"
means KPC and its affiliates, including Holdings, other than the Company and its
subsidiaries.
Indemnification. As of December 31, 1997, the consolidated financial
statements of Holdings contained liabilities to third parties, including tax
liabilities, aggregating approximately $66 million incurred by the Non-Drilling
Subsidiaries on or before March 31, 1997. Holdings maintains cash and cash
equivalents (the "Liability Payment Fund") which will be used to satisfy those
liabilities remaining after such date. The Company, Holdings and KPC have agreed
in the Intercompany Agreement that all amounts paid to claimants to satisfy
those liabilities, whether by settlement, judgment or award (including
claimants' attorneys' fees), will be paid by Holdings from the Liability Payment
Fund. The Company will pay all internal and external costs and fees (including
the Company's and Holdings' attorneys' fees) associated with management and
resolution of those liabilities, and believes such costs and fees will not be
material. If any amount remains in the Liability Payment Fund at March 31, 2002,
Holdings will pay the Company the first $10 million of such amount and 50% of
any amount in excess of $10 million. Thereafter, or if the resolution of those
liabilities earlier exhausts the Liability Payment Fund, Holdings will have no
further responsibility for those liabilities, and the Company will be
responsible for all costs, fees and amounts paid to resolve those liabilities
and will indemnify the KPC Affiliated Group in respect of such costs and fees
and those liabilities. The Company believes that the Liability Payment Fund is
adequate to provide for such costs and fees and those liabilities. Accordingly,
the Company believes that the indemnification costs, if any, will not be
material and no additional reserves have been established by the Company in
respect of such costs and fees and those liabilities or the Company's obligation
under the Intercompany Agreement relating to such costs and fees and those
liabilities. See "-- Management Services Agreement."
The Intercompany Agreement also provides that, except as may be provided in
a separate agreement, the Company will indemnify the KPC Affiliated Group
against losses based on, or taxes arising from, the following: (i) the ownership
of the assets or the operation of the business of the Company or its
subsidiaries, (ii) any other activities of the Company or its subsidiaries,
(iii) any guaranty or similar agreement by the KPC Affiliated Group provided to
any person with respect to any obligation of the Company or its subsidiaries,
and (iv) certain other matters. In addition, the Company has agreed to indemnify
the KPC Affiliated Group against certain civil liabilities, including
liabilities under the Securities Act of 1933, as amended (the "Securities Act"),
relating to misstatements in or omissions from the Registration Statement filed
in respect of the Offering and any other registration statement or report that
the Company files under the Securities Act. Holdings has also agreed to
indemnify the Company and its subsidiaries against losses based on the ownership
or operation of the assets or properties or the operation or conduct of the
business of Holdings and its subsidiaries on or after March 31, 1997.
Consent of Holdings to Certain Events. The Intercompany Agreement provides
that until members of the KPC Affiliated Group cease to own the lesser of at
least 25% of the outstanding Ordinary Shares or 25% of the Company's outstanding
voting shares, the prior consent of Holdings generally will be required for: (i)
any disposition by the Company of assets involving consideration in excess of
$50 million; (ii) any issuance by the Company or any subsidiary of the Company
of any equity securities; (iii) the incurrence of any indebtedness or guaranty
in a consolidated amount in excess of $250 million at any time outstanding; and
(iv) a change in corporate domicile of the Company or any of its subsidiaries.
Analogous provisions are contained in the Articles. Under this arrangement,
consents may be requested from time to time. In the event Holdings does
41
<PAGE> 44
not respond within 30 days after receipt of written notice from the Company
requesting consent to a proposed action, then the consent will be deemed to have
been given by Holdings to the Company.
Registration Rights. The Company has granted to the KPC Affiliated Group
certain demand and "piggyback" registration rights with respect to equity
securities owned by it. Pursuant to the demand registration rights, the KPC
Affiliated Group may, at any time, request the Company to register under the
Securities Act any or all Ordinary Shares held by the KPC Affiliated Group
whenever it wishes to sell Ordinary Shares in a transaction it reasonably
expects will yield gross proceeds of at least $250 million. The Company has
agreed to use its best efforts to effect any demand registrations requested by
the KPC Affiliated Group and has also agreed to register under the Securities
Act a certain amount of Ordinary Shares held by the KPC Affiliated Group when
the Company initiates certain other registrations of equity securities of the
Company on its own behalf or on behalf of any shareholder of the Company. Such
registration rights are transferable by the KPC Affiliated Group. The Company
has agreed to pay all costs and expenses in connection with each such
registration, except underwriting discounts and commissions applicable to the
equity securities sold by the KPC Affiliated Group and its transferees. The
Intercompany Agreement also contains specified restrictions on the ability of
the KPC Affiliated Group to exercise its demand and piggyback registration
rights and also contains customary terms and provisions with respect to, among
other things, registration procedures and certain rights to indemnification
granted by parties thereunder in connection with the registration of Ordinary
Shares on behalf of the KPC Affiliated Group under the Securities Act and
otherwise.
Other Provisions. Until the end of the first fiscal year of KPC in which
the KPC Affiliated Group owns the lesser of at least 25% of the outstanding
Ordinary Shares or 25% of the Company's outstanding voting shares, the Company
has agreed to furnish extensive financial information to Holdings, including
certain information before it becomes publicly available. So long as the KPC
Affiliated Group owns at least 10% of the outstanding Ordinary Shares or 10% of
the Company's outstanding voting shares, the Company has agreed to discuss its
affairs, finances and accounts with Holdings and to permit Holdings to inspect
its properties, corporate books, and financial and other records.
Management Services Agreement
The Company has also entered into a Management Services Agreement with
Holdings (the "Management Services Agreement") for the purpose of providing
asset (primarily real estate) management services, general and administrative
services and liability management and resolution services to Holdings, the Non-
Drilling Subsidiaries and inactive subsidiaries of Holdings. The Management
Services Agreement authorizes the Company to resolve the liabilities of the
Non-Drilling Subsidiaries described under "Intercompany Agreement" using the
Liability Payment Fund. Although Holdings retains the right to reduce or expand
the scope of services to be performed by the Company pursuant to the Management
Services Agreement, the Company's liability management and resolution services
may not be reduced or terminated. The Management Services Agreement also
provides for payment of an initial asset management fee to the Company of
$173,000 per year as well as reimbursement of out-of-pocket costs in respect of
asset management services, and stipulates that the fees are subject to
negotiation on an annual basis and upon any reduction in or expansion of the
scope of services provided by the Company. The Company will pay all internal and
external costs and fees (including the Company's and Holdings' attorneys' fees)
associated with the Company's liability management and resolution services and
all internal and external costs and fees associated with the provision of
general and administrative services pursuant to the Management Services
Agreement. The Company believes such costs and fees will not be material.
Charter Provisions Relating to Corporate Opportunities and Interested
Directors
The Company's Board of Directors currently includes persons who are also
Directors or officers of Holdings or KPC. As a consequence, Directors of the
Company who are also Directors or officers of KPC or Holdings charged with
granting or withholding consent for certain of the Company's actions may be
faced with conflicts of interest. In addition, potential conflicts of interest
exist or could arise in the future for such
42
<PAGE> 45
Directors with respect to a number of areas, including the Company's contract
drilling activities in Kuwait and its other business relationships with KPC
subsidiaries.
In order to address certain potential conflicts of interest between the
Company and the KPC Affiliated Group, the Articles contain provisions regulating
and defining the conduct of certain affairs of the Company as they may involve
the KPC Affiliated Group and their Directors and officers, and the powers,
rights, duties and liabilities of the Company and its officers, Directors and
shareholders in connection therewith. In general, these provisions recognize
that the Company and the KPC Affiliated Group may engage in the same line of
business and have an interest in the same areas of corporate opportunities and
that the Company and the KPC Affiliated Group will continue to have certain
contractual and business relations with each other (including service of
Directors and officers of the KPC Affiliated Group as Directors of the Company).
The Articles provide that the KPC Affiliated Group shall have no duty to
refrain from (i) engaging in the same line of business as the Company, (ii)
doing business with any customer of the Company or (iii) employing any employee
of the Company. The Articles also provide that the KPC Affiliated Group is not
under any duty to present any corporate opportunity to the Company which may be
a corporate opportunity for both the KPC Affiliated Group and the Company.
When corporate opportunities are offered to persons who are Directors or
officers of the Company and the KPC Affiliated Group, the Articles provide that
such Directors or officers of the Company shall not be liable to the Company or
its shareholders by reason of the fact that such members of the KPC Affiliated
Group pursue such corporate opportunities for themselves or do not present such
corporate opportunities to the Company, except in the case of wilful default or
fraud of such Directors or officers, if such Directors or officers act in a
manner consistent with a policy that provides for allocation based principally
on the capacities in which the individual Director or officer is offered the
opportunity.
The Articles also provide that no arrangement between the Company and the
KPC Affiliated Group or another related party shall be voidable, and no
liability shall be imposed, solely because a member of the KPC Affiliated Group
is a party thereto, or solely because any Directors or officers who are related
parties are present at, participate in or vote with respect to, the
authorization of the arrangement, except in the case of wilful default or fraud
on the part of the Directors or officers, if the material facts as to the
arrangement are disclosed to the Company's Board of Directors or the holders of
the Ordinary Shares who approve the arrangement.
The affirmative vote of a two-thirds majority of the shares entitled to
vote thereon and voting at a meeting of shareholders is required to amend the
Articles, including the provisions concerning corporate opportunity and
interested Directors described above and the provisions requiring the consent of
Holdings to certain actions described in "-- Intercompany Agreement -- Consent
of Holdings to Certain Events." Accordingly, so long as the KPC Affiliated Group
controls more than one third of such voting power, it can prevent any such
amendment.
CONSULTING AGREEMENT
On December 10, 1997, Gordon M. Anderson, a Director of the Company, and
the Company entered into a Consulting Agreement pursuant to which Mr. Anderson
shall serve as an independent consultant to the Company with respect to matters
relating to or affecting the operations of the Company. The term of the
Consulting Agreement is one year, terminating on January 1, 1999. Pursuant to
the Consulting Agreement, the Company has compensated Mr. Anderson by issuing to
Mr. Anderson 4,000 restricted Ordinary Shares under the Company's LTIP. In
addition, on the 25th month anniversary from the date of the grant of restricted
Ordinary Shares, the Company will further compensate Mr. Anderson under the
Consulting Agreement by paying Mr. Anderson cash in an amount equal to the
federal income tax payable with respect to the vesting of the 4,000 Ordinary
Shares and the federal income tax payable with respect to the cash payment to
Mr. Anderson. The Consulting Agreement also provides that Mr. Anderson will be
entitled to the standard Directors' cash and noncash compensation that all other
non-employee Directors are entitled to receive.
43
<PAGE> 46
PART II
ITEM 14. DESCRIPTION OF SECURITIES TO BE REGISTERED.
Not applicable.
PART III
ITEM 15. DEFAULTS UPON SENIOR SECURITIES.
None.
ITEM 16. CHANGES IN SECURITIES AND CHANGES IN SECURITY FOR REGISTERED
SECURITIES.
None.
PART IV
ITEM 17. FINANCIAL STATEMENTS.
Not applicable.
ITEM 18. FINANCIAL STATEMENTS.
See Item 19(a).
ITEM 19. FINANCIAL STATEMENTS AND EXHIBITS
(a) Financial Statements
See Index to Consolidated Financial Statements on page F-1.
(b) Exhibits
<TABLE>
<C> <S>
*1 -- U.S. and International Underwriting Agreements among the
Registrant and the various Underwriters, dated June 9,
1997.
**3.1 -- Amended and Restated Memorandum of Association of the
Registrant.
**3.2 -- Amended and Restated Articles of Association of the
Registrant.
*4 -- Specimen of Ordinary Shares Certificate.
**10.1 -- Registrant's Investment Savings and Profit Sharing Plan.
**10.2 -- Registrant's Pension Plan (U.S. employees).
**10.3 -- Registrant's Special Pension Plan (non-U.S. employees).
**10.4 -- Registrant's Equity Restoration Plan.
*10.5 -- Registrant's Supplemental Executive Retirement Plan.
*10.6 -- Registrant's Performance Unit Plan.
***10.7 -- Registrant's Annual Incentive Compensation Plan.
***10.8 -- Registrant's 1997 Long Term Incentive Plan.
***10.9 -- Registrant's 1997 Non-Employee Director Stock Option
Plan.
***10.10 -- Registrant's 1997 Employee Share Purchase Plan.
*10.11 -- Registrant's Employee Severance Protection Plan.
*10.12 -- Registrant's Directors and Officers Indemnity Agreement.
</TABLE>
44
<PAGE> 47
<TABLE>
<C> <S>
*10.13 -- Intercompany Agreement by and among Kuwait Petroleum
Corporation, SFIC Holdings (Cayman), Inc. and the
Registrant, dated June 9, 1997.
*10.14 -- Management Services Agreement by and between SFIC
Holdings (Cayman), Inc. and the Registrant, dated June 9,
1997.
**10.15 -- Agency Agreement between Kuwait Santa Fe Braun for
Engineering and Petroleum Enterprises (K.S.B.) Company
K.S.C. and the Registrant, dated April 1, 1992.
**10.16 -- Contract for the Construction and Sale of a Jackup
Drilling Unit by and between Far East Levingston
Shipbuilding Ltd. and the Registrant dated as of December
16, 1996.
**10.17 -- Drilling Contract by and between Mobil Oil Canada
Properties and Santa Fe Drilling Company (Canada)
Limited, dated as of December 16, 1996.
*10.18 -- Share Purchase Agreement between SFIC Holdings (Cayman)
Inc. and the Registrant, dated as of June 9, 1997.
*10.19 -- Contract for the Construction and Sale of Jackup Drilling
Unit Galaxy III by and between Keppel FELS Limited and
the Registrant, dated as of September 17, 1997.
*10.20 -- Letter of Interim Agreement for Provision of Jackup
Drilling Unit by and between Amoco (U.K.) Exploration
Company and the Registrant, dated as of September 3,
1997.
****10.21 -- Consulting Agreement dated December 10, 1997 between
Registrant and Gordon M. Anderson.
****10.22 -- AMOCO (U.K.) Exploration Company Form of Contract Ref:
AD3300 for The Provision of the Jack-Up Drilling Unit
Santa Fe "Galaxy III" for Drilling Operations on the
U.K.C.S. with Santa Fe Drilling Company (North Sea)
Limited, Dated September 3, 1997 (with Appendix 5 only).
**21 -- List of Subsidiaries.
23.1 -- Consent of Ernst & Young LLP, independent auditors
</TABLE>
- ---------------
* Incorporated by reference to the Company's Annual Report on Form 20-F for
the fiscal year ended June 30, 1997.
** Incorporated by reference to the Company's Registration Statement on Form
F-1 (No. 333-6912) filed May 14, 1997.
*** Incorporated by reference to the Company's Registration Statement on Form
S-8 (No. 333-7070) filed June 13, 1997.
**** Incorporated by reference to the Company's Report on Form 6-K filed March
3, 1998.
45
<PAGE> 48
SANTA FE INTERNATIONAL CORPORATION
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
Report of Independent Auditors.............................. F-1
Consolidated Statements of Operations for the six months
ended December 31, 1997 and 1996 and for the fiscal years
ended June 30, 1997, 1996, and 1995....................... F-2
Consolidated Balance Sheets as of December 31, 1997 and 1996
and June 30, 1997 and 1996................................ F-3
Consolidated Statements of Shareholders' Equity for the six
months ended December 31, 1997 and 1996 and for the fiscal
years ended June 30, 1997, 1996 and 1995.................. F-4
Consolidated Statements of Cash Flows for the six months
ended December 31, 1997 and 1996 and for the fiscal years
ended June 30, 1997, 1996 and 1995........................ F-5
Notes to the Consolidated Financial Statements.............. F-6
</TABLE>
<PAGE> 49
REPORT OF INDEPENDENT AUDITORS
Board of Directors and Shareholders
Santa Fe International Corporation
We have audited the accompanying consolidated balance sheets of Santa Fe
International Corporation and subsidiary companies (the Company) as of December
31, 1997 and 1996 and June 30, 1997 and 1996, and the related consolidated
statements of operations, shareholders' equity and cash flows for the six months
ended December 31, 1997 and 1996 and for each of the three fiscal years in the
periods ended June 30, 1997, 1996 and 1995. These financial statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the consolidated financial position of Santa Fe
International Corporation and subsidiary companies at December 31, 1997 and 1996
and June 30, 1997 and 1996, and the consolidated results of their operations and
their cash flows for the six months ended December 31, 1997 and 1996 and for
each of the three fiscal years in the periods ended June 30, 1997, 1996 and
1995, in conformity with generally accepted accounting principles in the United
States.
/s/ ERNST & YOUNG LLP
Dallas, Texas
January 28, 1998
F-1
<PAGE> 50
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(U.S. DOLLARS, IN THOUSANDS, EXCEPT SHARE AND PER SHARE DATA)
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
------------------------- ---------------------------------------
1997 1996 1997 1996 1995
----------- ----------- ----------- ----------- -----------
<S> <C> <C> <C> <C> <C>
Operating revenues (Notes 11 and
12)........................... $ 375,185 $ 264,791 $ 578,563 $ 470,882 $ 466,262
Operating costs and expenses:
Operating costs............... 195,678 161,510 339,665 308,513 320,317
Depreciation and amortization
(Note 3)................... 24,876 22,039 43,360 77,128 86,916
General and administrative.... 10,781 7,563 16,931 17,168 16,225
Gain on sale of assets........ (374) (789) (1,041) (754) (1,355)
----------- ----------- ----------- ----------- -----------
Total operating costs
and expenses........ 230,961 190,323 398,915 402,055 422,103
----------- ----------- ----------- ----------- -----------
Operating income................ 144,224 74,468 179,648 68,827 44,159
Other income (expense):
Investment income............. 1,364 2,548 5,702 10,071 7,630
Interest expense.............. -- -- -- (386) (5,107)
Other, net.................... (560) 1,981 891 (669) 2,571
----------- ----------- ----------- ----------- -----------
Income before provision for
taxes on income............... 145,028 78,997 186,241 77,843 49,253
Provision for taxes on income
(Note 5)...................... 16,500 10,339 21,325 15,867 4,955
----------- ----------- ----------- ----------- -----------
Net income............ $ 128,528 $ 68,658 $ 164,916 $ 61,976 $ 44,298
=========== =========== =========== =========== ===========
Income per ordinary share:
Basic and Diluted............. $ 1.12 $ 1.44
=========== ===========
Pro forma net income per
ordinary share:
Basic and Diluted............. $ 0.60 $ 0.54
=========== ===========
Weighted average ordinary and
ordinary equivalent shares
used in ordinary share
computations:
Basic......................... 114,500,000 114,500,000 114,500,000 114,500,000
=========== =========== =========== ===========
Diluted....................... 114,608,000 114,500,000 114,502,000 114,500,000
=========== =========== =========== ===========
</TABLE>
See notes to consolidated financial statements.
F-2
<PAGE> 51
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(U.S. DOLLARS, IN THOUSANDS, EXCEPT SHARE DATA)
ASSETS
<TABLE>
<CAPTION>
DECEMBER 31, JUNE 30,
---------------------- ----------------------
1997 1996 1997 1996
---------- -------- ---------- --------
<S> <C> <C> <C> <C>
Current assets:
Cash and cash equivalents.................. $ 68,453 $ 73,092 $ 38,933 $ 41,845
Marketable securities...................... 8,093 21,481 25,793 18,078
Accounts receivable (Note 12).............. 149,268 136,360 133,630 130,038
Inventories................................ 51,182 49,783 46,455 42,689
Prepaid expenses and other current
assets.................................. 17,459 10,444 13,768 13,083
---------- -------- ---------- --------
Total current assets............... 294,455 291,160 258,579 245,733
---------- -------- ---------- --------
Marketable securities........................ -- -- -- 5,280
Property and equipment, at cost (Note 3)..... 1,737,285 1,504,391 1,605,619 1,460,616
Less accumulated depreciation and
amortization............................ (935,315) (894,175) (914,319) (873,196)
---------- -------- ---------- --------
Property and equipment, net................ 801,970 610,216 691,300 587,420
Prepaid deposits............................. 14,861 -- -- --
Other noncurrent assets (Notes 5 and 7)...... 50,167 46,856 50,567 46,565
---------- -------- ---------- --------
Total assets....................... $1,161,453 $948,232 $1,000,446 $884,998
========== ======== ========== ========
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
Accounts payable........................... $ 92,014 $ 56,734 $ 61,655 $ 66,112
Accrued liabilities (Note 4)............... 79,741 61,799 71,194 55,288
---------- -------- ---------- --------
Total current liabilities.......... 171,755 118,533 132,849 121,400
Other noncurrent liabilities (Note 6)........ 36,681 31,778 36,482 30,506
---------- -------- ---------- --------
Total liabilities.................. 208,436 150,311 169,331 151,906
Commitments and contingencies (Note 10)
Shareholders' equity (Notes 1 and 8):
Ordinary shares par value $.01; 600,000,000
shares authorized, 114,746,550,
84,500,000, 114,500,000 and 84,500,000
shares issued and outstanding at
December 31, 1997 and 1996, and June 30,
1997 and 1996, respectively............. 1,147 845 1,145 845
Additional paid-in capital................... 665,869 728,418 665,054 732,247
Retained earnings............................ 286,001 68,658 164,916 --
---------- -------- ---------- --------
Total shareholders' equity......... 953,017 797,921 831,115 733,092
---------- -------- ---------- --------
Total liabilities and shareholders'
equity........................... $1,161,453 $948,232 $1,000,446 $884,998
========== ======== ========== ========
</TABLE>
See notes to consolidated financial statements.
F-3
<PAGE> 52
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
(U.S. DOLLARS, IN THOUSANDS, EXCEPT SHARE DATA)
<TABLE>
<CAPTION>
NET
UNREALIZED
ORDINARY SHARES ADDITIONAL SHAREHOLDERS' GAINS ON TOTAL
----------------------- PAID-IN RETAINED NET MARKETABLE SHAREHOLDERS'
SHARES PAR VALUE CAPITAL EARNINGS INVESTMENT SECURITIES EQUITY
----------- --------- ---------- -------- ------------- ---------- -------------
<S> <C> <C> <C> <C> <C> <C> <C>
BALANCE AT JUNE 30,
1994................... -- $ -- $ -- $ -- $ 749,328 $ -- $ 749,328
Adjustment for the
cumulative effect of
the change in method
of accounting for
marketable securities
(Note 2)............. -- -- -- -- -- 5,925 5,925
Distributions to
parent............... -- -- -- -- (72,483) -- (72,483)
Adjustment to
unrealized gains on
available-for-sale
securities........... -- -- -- -- -- 1,021 1,021
Net income............. -- -- -- -- 44,298 -- 44,298
----------- ------ -------- -------- --------- ------- ---------
BALANCE AT JUNE 30,
1995................... -- -- -- -- 721,143 6,946 728,089
Distributions to
parent............... -- -- -- -- (50,027) -- (50,027)
Adjustment to
unrealized gains on
available-for-sale
securities........... -- -- -- -- -- (6,946) (6,946)
Net income............. -- -- -- -- 61,976 -- 61,976
Reclassification of
shareholder's net
investment (Note
1)................... 84,500,000 845 732,247 -- (733,092) -- --
----------- ------ -------- -------- --------- ------- ---------
BALANCE AT JUNE 30,
1996................... 84,500,000 845 732,247 -- -- -- 733,092
Distribution to
parent............... -- -- (3,829) -- -- -- (3,829)
Net income............. -- -- -- 68,658 -- -- 68,658
----------- ------ -------- -------- --------- ------- ---------
BALANCE AT DECEMBER 31,
1996................... 84,500,000 845 728,418 68,658 -- -- 797,921
Ordinary shares issued
for cash, net (Note
1)................... 40,000,000 400 1,080,320 -- -- -- 1,080,720
Purchase of ordinary
shares form Holdings
(Note 1)............. (10,000,000) (100) (272,080) -- -- -- (272,180)
Distributions to
parent............... -- -- (871,604) -- -- -- (871,604)
Net income............. -- -- -- 96,258 -- -- 96,258
----------- ------ -------- -------- --------- ------- ---------
BALANCE AT JUNE 30,
1997................... 114,500,000 1,145 665,054 164,916 -- -- 813,115
Ordinary shares issued
pursuant to employee
benefit plans........ 246,550 2 815 -- -- -- 817
Dividends.............. -- -- -- (7,443) -- -- (7,443)
Net Income............. -- -- -- 128,528 -- -- 128,528
----------- ------ -------- -------- --------- ------- ---------
BALANCE AT DECEMBER 31,
1997................... 114,746,550 $1,147 $665,869 $286,001 $ -- $ -- $ 953,017
=========== ====== ======== ======== ========= ======= =========
</TABLE>
See notes to consolidated financial statements.
F-4
<PAGE> 53
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(U.S. DOLLARS, IN THOUSANDS)
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
-------------------- ---------------------------------
1997 1996 1997 1996 1995
--------- -------- ---------- --------- --------
<S> <C> <C> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income.................................. $ 128,528 $ 68,658 $ 164,916 $ 61,976 $ 44,298
Adjustments to reconcile net income to net
cash provided by operating activities:
Depreciation and amortization............. 24,876 22,039 43,360 77,128 86,916
Gain on sale of assets.................... (374) (789) (1,041) (754) (1,355)
Accretion of interest income and gains on
sales of marketable securities......... (508) (2,795) (4,643) (9,866) (7,588)
Deferred income tax provision (benefit)... 2,545 1,504 2,381 4,452 (7,870)
Changes in operating assets and liabilities:
Accounts receivable....................... (15,638) (6,322) (3,592) (27,066) (17,658)
Inventories............................... (4,727) (7,094) (3,766) (5,274) (1,693)
Prepaid expenses and other................ (3,691) 2,639 (685) 1,440 2,525
Accounts payable.......................... 30,359 (9,378) (4,457) 23,204 19,097
Accrued liabilities....................... 4,825 6,511 15,906 (9,704) 19,828
Other, net................................ (1,526) (920) (1,201) (2,418) (4,815)
--------- -------- ---------- --------- --------
Net cash provided by operating
activities...................... 164,669 74,053 207,178 113,118 131,685
Capital expenditures........................ (127,133) (44,537) (146,596) (64,810) (36,443)
Advance payments for drilling rigs.......... (23,111) -- -- -- --
Proceeds from sales of property and
equipment................................. 608 888 1,191 1,490 4,397
Maturities of marketable securities......... 44,050 20,545 44,986 -- 17,403
Sales of marketable securities.............. -- -- -- 91,881 --
Purchases of marketable securities.......... (25,842) (15,873) (42,778) (23,549) --
--------- -------- ---------- --------- --------
Net cash provided by (used for)
investing activities............ (131,428) (38,977) (143,197) 5,012 (14,643)
Cash flows from financing activities:
Sale of ordinary shares, net.............. -- -- 1,080,720 -- --
Purchase of ordinary shares from
Holdings............................... -- -- (272,180) -- --
Distributions to parent, net.............. -- (3,829) (875,433) (50,027) (72,483)
Dividends paid............................ (3,721) -- -- -- --
Repayments of capital lease obligations... -- -- -- (58,364) (25,890)
--------- -------- ---------- --------- --------
Net cash used for financing
activities...................... (3,721) (3,829) (66,893) (108,391) (98,373)
--------- -------- ---------- --------- --------
Net change in cash and cash equivalents..... 29,520 31,247 (2,912) 9,739 18,669
Cash and cash equivalents at beginning of
period.................................... 38,933 41,845 41,845 32,106 13,437
--------- -------- ---------- --------- --------
Cash and cash equivalents at end of
period.................................... $ 68,453 $ 73,092 $ 38,933 $ 41,845 $ 32,106
========= ======== ========== ========= ========
Supplemental disclosures of cash flows
information:
Interest paid............................. $ -- $ -- $ -- 1,947 $ 5,260
========= ======== ========== ========= ========
Income taxes paid......................... $ 7,587 $ 4,207 $ 11,819 $ 9,440 $ 6,667
========= ======== ========== ========= ========
</TABLE>
See notes to consolidated financial statements.
F-5
<PAGE> 54
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 1997
1. BASIS OF PRESENTATION AND DESCRIPTION OF BUSINESS
Santa Fe International Corporation (the "Company"), a Cayman Islands
corporation, is a majority-owned subsidiary of SFIC Holdings (Cayman), Inc.
("Holdings"), which in turn is a wholly-owned subsidiary of Kuwait Petroleum
Corporation ("KPC"). KPC is wholly owned by the Government of Kuwait. In a
series of transactions during the four years ended December 31, 1996, Holdings
and its subsidiaries were reorganized in a manner which resulted in the Company
owning all of the drilling assets and the direct and indirect subsidiaries of
Holdings and KPC engaged in providing contract drilling and drilling related
services (the "Reorganization"). The actions taken in connection with the
Reorganization have been accounted for as a reorganization of entities under
common control in a manner similar to a pooling of interests. For financial
reporting purposes the historical equity accounts of the Company, its
subsidiaries and its predecessors for dates prior to June 30, 1996 (the date at
which the Reorganization was substantially complete) have been combined into a
single disclosure caption entitled "Shareholder's Net Investment."
On May 27, 1997, the Company was recapitalized, resulting in the Company's
900,000 authorized ordinary shares, par value $1.00 per share, with 1,003
ordinary shares issued and outstanding, being recapitalized into 600,000,000
authorized ordinary shares, par value $0.01 per share ("Ordinary Shares"), with
84,500,000 Ordinary Shares issued and outstanding. The accompanying consolidated
financial statements have been adjusted to reflect this recapitalization
retroactively.
On June 9 and 13, 1997, respectively, the Company commenced and completed
an initial public offering (the "Offering") of Ordinary Shares. Upon the
issuance of 40,000,000 Ordinary Shares in the Offering and consummation of the
purchase described below of Ordinary Shares from Holdings, the Company had
114,500,000 Ordinary Shares outstanding. Immediately following the Offering,
Holdings held 65.1% of the outstanding Ordinary Shares of the Company. The
Offering price was $28.50 per share, resulting in net proceeds of approximately
$1,088,720,000 after deducting underwriting discounts and commissions. The
Company also incurred approximately $8 million of expenses in connection with
the Offering which has been charged to additional paid-in-capital. Upon receipt
of proceeds from the sale of the first 30,000,000 Ordinary Shares sold in the
Offering, the Company paid a cash dividend to Holdings in an amount equal to
those proceeds. All of the proceeds the Company received from the sale in the
Offering of Ordinary Shares in excess of that amount were used to purchase a
like number of Ordinary Shares from Holdings.
Holders of Ordinary Shares are entitled to participate in the payment of
dividends in proportion to their holdings. Under Cayman Island law, the Company
may pay dividends or make other distributions to its shareholders, in such
amounts as the Board of Directors deems appropriate from the profits of the
Company or out of the Company's share premium account (equivalent to additional
paid-in capital) if the Company thereafter has the ability to pay its debts as
they come due. Cash dividends, if any, will be declared and paid in U.S.
dollars. At December 31, 1997 the Company had declared dividends which had not
been paid amounting to $3,722,000.
The Company operates in one business segment, providing contract drilling
and related services throughout the world.
At the direction of the Board of Directors, the Company has implemented a
change from a June 30 fiscal year end to a December 31 fiscal year end effective
January 1, 1998.
The accompanying consolidated financial statements are presented in U.S.
dollars and in accordance with U.S. generally accepted accounting principles.
F-6
<PAGE> 55
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Consolidation
The Company consolidates all of its majority-owned subsidiaries. The
Company also consolidates joint ventures over which the Company exercises
control through the joint venture agreement or related operating and financing
agreements. The Company accounts for its interest in other joint ventures using
the equity method. All material intercompany accounts and transactions are
eliminated in consolidation.
Accounting Estimates
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent 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 these estimates.
Cash Equivalents and Marketable Securities
Cash equivalents consist of highly liquid short-term investments that are
readily convertible into cash and which at the date of purchase were so near
their maturity that they expose the Company to an insignificant risk from
changes in interest rates. Cash equivalents are carried at cost plus accrued
interest, which approximates fair value. The interest method is used to account
for any premium or discount on cash equivalents. The Company's policy is to
place its temporary cash investments with high credit quality financial
institutions and by policy limit the amount of credit exposure to any one
financial institution.
Effective July 1, 1994, the Company adopted Statement of Financial
Accounting Standards ("SFAS") No. 115, "Accounting for Certain Investments in
Debt and Equity Securities". All marketable securities and long-term investments
are classified as available-for-sale securities under SFAS No. 115. Unrealized
holding gains and losses on securities available-for-sale are recorded as a
component of shareholder's equity, net of tax effect. The fair values for
marketable securities are based on quoted market prices. The amortized cost of
debt securities in this category is adjusted for amortization of premiums and
accretion of discounts to maturity. Such amortization is include in investment
income. Realized gains and losses and declines in value judged to be
other-than-temporary on available-for-sale securities are included in investment
income. Adoption of SFAS No. 115 resulted in an increase in shareholder's equity
of $5,925,000 at July 1, 1994. The Company does not believe that it is exposed
to any significant risks on its investments.
At December 31, 1997 and June 30, 1997, marketable securities consisted
only of Eurodollar debt securities.
Investment income included realized gains on sales of marketable securities
of $3,863,000 for the fiscal year ended June 30, 1996.
Inventories
Inventories consist primarily of materials and supplies which are used in
operations and are stated at the lower of cost (determined principally by the
average cost or specific identification method) or estimated net realizable
value.
F-7
<PAGE> 56
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
Concentrations of Credit Risk
The Company's customers consist primarily of major international, state
owned and large independent oil companies and their affiliates. The Company
provides allowances for potential credit losses when necessary. The Company did
not incur any charges for credit losses during the periods presented.
Property and Equipment
Property and equipment is carried at cost. Maintenance and repairs are
charged to expense currently while major replacements and upgrades are
capitalized. Upon retirement or other disposal of fixed assets, the cost and
related accumulated depreciation are removed from the respective accounts and
any gains or losses are included in the results of operations. Property and
equipment is depreciated on the straight-line method, after allowing for salvage
values, over the remaining estimated useful lives from the date the asset is
placed into service.
The Company reviews its long-term assets for impairment when changes in
circumstances indicate that the carrying amount of an asset may not be
recoverable. In 1996, the Company adopted SFAS No. 121, "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of".
SFAS No. 121 requires that long-lived assets and certain identifiable
intangibles to be held and used be reported at the lower of carrying amount or
fair value. Assets to be disposed of and assets not expected to provide any
future service potential to the Company are recorded at the lower of carrying
amount or fair value less cost to sell. The adoption of SFAS No. 121 did not
affect the Company's financial position or results of operations.
Operating Revenues and Costs
The majority of the Company's drilling contracts are performed on a dayrate
basis, with revenues and expenses recognized as work is performed. The Company
also operates under incentive-based contracts, such as turnkey drilling and
footage contracts, under the terms of which the Company may earn additional
revenues by exceeding preset conditions of job performance. The Company
recognizes incremental revenues from these incentive-based contracts when such
conditions of the contract have been achieved. Under certain incentive-based
contracts, the Company may incur penalties or reduced remuneration if preset
conditions are not achieved. The Company recognizes the effect of such penalties
or reduced remuneration, which historically has been immaterial, as an
adjustment to incentive revenues when the amount reasonably can be estimated.
In connection with drilling contracts, the Company may receive lump sum
fees for the mobilization of equipment and personnel or for capital improvements
to rigs. In connection with mobilization reimbursements, the net of mobilization
fees received and expenses incurred is recognized over the term of the drilling
contract. Costs of relocating drilling units without contracts are expensed as
incurred. Demobilization fees received are reflected in income, net of any
related expense. Capital upgrade fees received from the client are deferred and
recognized as revenue over the period of the drilling contract. The actual cost
incurred for the capital upgrade is capitalized and depreciated over the
estimated useful life of the asset.
The Company also earns revenue by providing drilling related services.
Revenues from third party rig operations, drilling engineering and integrated
well services are recognized as the services are performed. Revenues from
drilling project management contracts are recognized using the percentage of
completion method based on the ratio of costs incurred to total estimated
contract costs. Provisions for losses are recorded for contracts in progress
when losses are anticipated.
Income Taxes
The Company is not subject to income taxes in the Cayman Islands. The
current provision for taxes on income consists primarily of income taxes based
on the tax laws and rates of the countries in which operations
F-8
<PAGE> 57
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
were conducted during the periods presented. Certain of the Company's operations
were included in consolidated income tax returns of affiliates during the
periods presented. Under tax sharing agreements, the Company provides for income
taxes payable to such affiliates as if it filed separate income tax returns.
The Company computes its provision for deferred income taxes using the
liability method. Under the liability method, deferred income tax assets and
liabilities are determined based on differences between financial reporting and
income tax bases of assets and liabilities and are measured using the enacted
tax rates and laws. The measurement of deferred tax assets is adjusted by a
valuation allowance, if necessary, to recognize the future tax benefits to the
extent, based on available evidence, it is more likely than not they will be
realized.
Foreign Currency Translation
The functional currency of the primary economic environments in which the
Company operates is the U.S. dollar. Gains and losses resulting from the
remeasurement of local currencies into U.S. dollars are included in the results
of operations of the current period. The Company periodically reviews the
operations of its entities to ensure the functional currency of each entity is
the currency of the primary economic environment in which it operates.
Share Options and Awards
The Company has elected to follow Accounting Principles Board Opinion No.
25, "Accounting for Stock Issued to Employees" (APB 25) in accounting for its
employee share options. Under APB 25, if the exercise price of an employee's
share option equals or exceeds the market price of the underlying share on the
date of grant, no compensation expense is recognized.
Income Per Ordinary Share
The basic and diluted income per Ordinary Share data for the six months
ended December 31, 1997 and for the fiscal year ended June 30, 1997 is
calculated based on the weighted average shares outstanding for the periods. The
pro forma income per share data for the six months ended December 31, 1996 and
fiscal year ended June 30, 1996 is calculated as though the 114,500,000 shares
issued in connection with the recapitalization and the Offering were outstanding
for the periods then ended. At December 31, 1997 the Company adopted SFAS No.
128, "Earnings Per Share." Accordingly, the financial statements have been
restated as applicable. The effect of the adoption of this statement was not
material.
3. PROPERTY AND EQUIPMENT
Property and equipment is summarized as follows (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31, JUNE 30,
ESTIMATED ----------------------- -----------------------
USEFUL LIVES 1997 1996 1997 1996
------------- ---------- ---------- ---------- ----------
<S> <C> <C> <C> <C> <C>
Drilling rigs and
equipment.............. 3 to 30 years $1,493,888 $1,372,160 $1,446,724 $1,365,419
Buildings, facilities and
camps.................. 4 to 10 years 48,763 45,136 45,896 44,880
Transportation
equipment.............. 3 to 5 years 14,107 11,570 13,367 11,229
Land..................... 204 960 849 960
Construction in
progress............... 180,323 74,565 98,783 38,128
---------- ---------- ---------- ----------
$1,737,285 $1,504,391 $1,605,619 $1,460,616
========== ========== ========== ==========
</TABLE>
F-9
<PAGE> 58
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
Following several years of strengthened demand for drilling rigs and
improving market conditions, during 1996 the Company's management undertook
engineering and economic studies to evaluate the economic useful lives of its
drilling rigs. Such studies included evaluation of current and future new rig
building costs, technological enhancements, rig maintenance and repair costs,
and market demand factors. The study results indicated that, given the current
condition of the rigs, the lack of new entrants into the market, and continuing
overall market improvements, the estimated useful lives should be extended by 12
years from 18 to 30 years for marine rigs and by four years from 12 to 16 years
for land rigs. The Company's Board of Directors approved application of the
change in useful lives effective July 1, 1996, which reduced depreciation
expense and increased net income, by approximately $34.5 million for the fiscal
year ended June 30, 1997. The reduction in depreciation expense did not result
in an increase in the provision for taxes on income. See Note 5.
4. ACCRUED LIABILITIES
Accrued liabilities consist of the following (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31, JUNE 30,
------------------ ------------------
1997 1996 1997 1996
------- ------- ------- -------
<S> <C> <C> <C> <C>
Compensation and benefits................. $26,604 $18,253 $25,273 $18,136
Deferred revenue.......................... 3,840 4,132 5,444 2,236
Income taxes (Note 5)..................... 41,364 32,076 34,964 26,734
Accrued insurance......................... 2,263 6,337 4,912 6,865
Other..................................... 5,670 1,001 601 1,317
------- ------- ------- -------
$79,741 $61,799 $71,194 $55,288
======= ======= ======= =======
</TABLE>
F-10
<PAGE> 59
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
5. INCOME TAXES
The Company is not subject to income taxes in the Cayman Islands. All of
the Company's income before provision for taxes on income and the related
provision for taxes on income relates to operations in jurisdictions other than
the Cayman Islands. The relationship between income before provision for taxes
on income and the provision for taxes on income varies from period to period
because each jurisdiction in which the Company operates has its own system of
taxation (not only with respect to the nominal rate, but also with respect to
the allowability of deductions, credits and other benefits) and because the
amounts earned in, and subject to tax by, each jurisdiction changes from period
to period. The reconciliation of income taxes computed at the applicable
statutory rates of the jurisdictions in which the Company's operations are
located and the provision for taxes on income is as follows (in thousands):
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
------------------- ------------------------------
1997 1996 1997 1996 1995
-------- -------- -------- -------- --------
<S> <C> <C> <C> <C> <C>
Provision for taxes on income at
the applicable statutory rates
of the jurisdictions in which
the Company's operations
are located................... $ 52,704 $ 26,717 $ 65,459 $ 26,487 $ 19,396
Effect of income taxed at rates
other than the statutory rates
of jurisdictions in which the
Company's operations
are located................... (31,538) (17,710) (40,024) (10,790) (4,093)
Benefit of additional
tax depreciation.............. (8,411) -- (8,050) -- --
Taxes on income resulting from
indexation.................... 436 -- 2,193 -- --
Benefit of net operating loss
carryforwards................. (298) (184) (13) (505) (11,070)
Net operating losses not
recognized.................... 3,607 1,516 1,760 675 722
-------- -------- -------- -------- --------
Provision for taxes on income... $ 16,500 $ 10,339 $ 21,325 $ 15,867 $ 4,955
======== ======== ======== ======== ========
</TABLE>
The components of the provision for taxes on income are as follows (in
thousands):
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
----------------- ---------------------------
1997 1996 1997 1996 1995
------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C>
Current provision.................... $13,955 $ 8,835 $18,944 $11,415 $12,825
Deferred provision (benefit)......... 2,545 1,504 2,381 4,452 (7,870)
------- ------- ------- ------- -------
Provision for taxes on income........ $16,500 $10,339 $21,325 $15,867 $ 4,955
======= ======= ======= ======= =======
</TABLE>
F-11
<PAGE> 60
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
The Company's net deferred tax liabilities and assets consist of the
following (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31, JUNE 30,
----------------- -----------------
1997 1996 1997 1996
------- ------- ------- -------
<S> <C> <C> <C> <C>
Deferred tax liabilities:
Property and equipment....................... $(4,838) $ -- $(2,787) $ --
Other........................................ 714 -- (251) --
------- ------- ------- -------
(5,552) -- (3,038) --
Net operating loss carryforwards:
Australia.................................... 3,602 1,453 2,758 1,397
Venezuela.................................... 1,041 -- -- --
Oman......................................... 196 -- -- --
Indonesia.................................... 4,648 -- 2,016 --
Tunisia...................................... 1,188 -- 644 184
U.K.......................................... -- 1,914 898 3,418
U.S.......................................... 584 1,460 1,500 --
------- ------- ------- -------
Total deferred income tax assets..... 11,259 4,827 7,816 4,999
Valuation allowance............................ (6,935) (2,913) (3,329) (1,581)
------- ------- ------- -------
4,324 1,914 4,487 3,418
------- ------- ------- -------
Net deferred income tax assets (liabilities)... $(1,228) $ 1,914 $ 1,449 $ 3,418
======= ======= ======= =======
</TABLE>
The Company's net operating loss carryforwards include tax effected losses
of $7,657,000 that expire between 1999 and 2012. The remaining $3,602,000 of net
operating losses do not expire.
The Company's income tax returns are subject to review and examination in
the various jurisdictions in which the Company operates. At December 31, 1997
and 1996 and June 30, 1997 and 1996, accrued income taxes include $24,798,000,
$22,972,000, $26,502,000 and $21,295,000, respectively, representing estimated
liabilities which will result from final settlements of such reviews and
examinations. The Company believes that all income tax issues which have been or
may be raised as a result of such reviews and examinations will be resolved with
no additional material impact on the Company's financial position or results of
operations.
6. OTHER NONCURRENT LIABILITIES
Other noncurrent liabilities consist of the following (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31, JUNE 30,
----------------- -----------------
1997 1996 1997 1996
------- ------- ------- -------
<S> <C> <C> <C> <C>
Pension benefits (Note 7)...................... $ 7,281 $ 9,188 $ 9,370 $ 8,548
Postretirement health and insurance benefits
(Note 7)..................................... 14,882 15,392 15,225 15,687
Deferred Taxes................................. 1,228 -- -- --
Other.......................................... 13,290 7,198 11,887 6,271
------- ------- ------- -------
$36,681 $31,778 $36,482 $30,506
======= ======= ======= =======
</TABLE>
F-12
<PAGE> 61
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
7. EMPLOYEE BENEFIT PLANS
Pensions
The Company maintains trusteed non-contributory and contributory defined
benefit plans which cover substantially all U.S. citizen and certain U.S.
resident non-citizen employees (the "Qualified Pension Plan") and all U.K.
resident employees (the "North Sea Pension Plan"). Additional pension benefits
in excess of those provided under the North Sea Pension Plan are provided to
eligible participants under the North Sea Supplementary Pension Plan. The
benefits under these plans are based on years of service and compensation
levels. The Company's funding policy, with respect to these plans, is to make
contributions annually equal to, or in excess of, statutory minimum funding
requirements. Trusteed assets of these plans consist principally of investments
in mutual funds. These plans also cover certain employees of affiliates. The
Company allocates benefit costs to affiliates based on the ratio of the pension
benefit obligation of affiliate participants to the total pension benefit
obligation. The Company also sponsors a defined benefit plan (the "Offshore
Plan") which covers certain other non U.S. employees. In addition, the Company
maintains plans (the "Supplemental Executive Retirement Plan" and the "Equity
Restoration Plan") to provide its eligible participants with benefits in excess
of those allowed under the Qualified Pension Plan. The Company funding policy
with respect to the Offshore Plan, the Supplemental Executive Plan and the
Equity Restoration Plan is to fund benefit obligations when such obligations
become payable to participants. Net periodic pension costs relating to the
Company's defined benefit plans consist of the following (in thousands):
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
------------------ -----------------------------
1997 1996 1997 1996 1995
------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C>
Service cost..................... $ 2,202 $ 1,968 $ 4,012 $ 3,876 $ 3,746
Interest cost.................... 3,004 2,808 5,674 5,051 4,419
Actual return on plan assets..... (8,729) (1,866) (5,612) (5,930) (6,029)
Net amortization and deferrals... 5,381 (881) 20 1,380 2,861
Costs charged to affiliates...... -- -- -- -- (631)
------- ------- ------- ------- -------
Net periodic pension
cost................. $ 1,858 $ 2,029 $ 4,094 $ 4,377 $ 4,366
======= ======= ======= ======= =======
</TABLE>
F-13
<PAGE> 62
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
The following table sets forth the funded status of the Company's defined
benefit plans and the related amounts included in other noncurrent assets and
liabilities (in thousands):
<TABLE>
<CAPTION>
U.S. PLANS WITH OBLIGATIONS LESS THAN ASSETS
--------------------------------------------
DECEMBER 31, JUNE 30,
-------------------- --------------------
1997 1996 1997 1996
-------- -------- -------- --------
<S> <C> <C> <C> <C>
QUALIFIED PENSION PLAN
Plan assets at fair value................... $60,243 $50,263 $54,260 $44,757
Actuarial present value of projected benefit
obligation:
Vested.................................... 42,633 38,131 38,394 35,869
Nonvested................................. 637 697 704 656
------- ------- ------- -------
Accumulated benefit obligation.............. 43,270 38,828 39,098 36,525
Effect of projected salary increases........ 5,907 5,521 5,417 5,133
------- ------- ------- -------
Projected benefit obligation................ 49,177 44,349 44,515 41,658
------- ------- ------- -------
Plan assets in excess of projected benefit
obligation................................ 11,066 5,914 9,745 3,099
Unrecognized prior service cost............. 489 842 666 1,017
Unrecognized net gain (loss)................ (5,850) 13 (4,421) 1,270
Unrecognized transition net asset........... 256 314 285 342
------- ------- ------- -------
Accrued pension asset recognized in the
consolidated balance sheets............... $ 5,961 $ 7,083 $ 6,275 $ 5,728
======= ======= ======= =======
</TABLE>
<TABLE>
<CAPTION>
NON-U.S. PLANS WITH OBLIGATIONS LESS THAN ASSETS
------------------------------------------------
DECEMBER 31, JUNE 30,
---------------------- ----------------------
1997 1996 1997 1996
--------- --------- --------- ---------
<S> <C> <C> <C> <C>
NORTH SEA PENSION PLAN AND NORTH SEA
SUPPLEMENTARY PENSION PLAN
Plan assets at fair value................... $34,699 $26,770 $29,333 $22,828
Actuarial present value of projected benefit
obligation:
Vested.................................... 21,805 16,564 19,981 13,745
Nonvested................................. -- -- -- --
------- ------- ------- -------
Accumulated benefit obligation.............. 21,805 16,564 19,981 13,745
Effect of projected salary increases........ 5,598 4,355 5,266 3,604
------- ------- ------- -------
Projected benefit obligation................ 27,403 20,919 25,247 17,349
------- ------- ------- -------
Plan assets in excess of projected benefit
obligation................................ 7,295 5,851 4,086 5,479
Unrecognized net loss....................... (3,758) (3,111) (915) (3,291)
Unrecognized transition net liability....... (529) (580) (545) (545)
------- ------- ------- -------
Accrued pension asset recognized in the
consolidated balance sheets............... $ 3,008 $ 2,160 $ 2,626 $ 1,643
======= ======= ======= =======
</TABLE>
F-14
<PAGE> 63
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
<TABLE>
<CAPTION>
U.S. PLANS WITH OBLIGATIONS IN EXCESS OF ASSETS
-------------------------------------------------
DECEMBER 31, JUNE 30,
----------------------- ----------------------
1997 1996 1997 1996
---------- --------- --------- ---------
<S> <C> <C> <C> <C>
OFFSHORE PLAN, SUPPLEMENTAL EXECUTIVE
RETIREMENT PLAN AND EQUITY RESTORATION
PLAN
Plan assets at fair value.................. $ -- $ -- $ -- $ --
Actuarial present value of projected
benefit obligation:
Vested................................... 5,481 4,741 3,049 4,369
Nonvested................................ 3,607 1,756 3,486 1,601
-------- ------- ------- -------
Accumulated benefit obligation............. 9,088 6,497 6,535 5,970
Effect of projected salary increases....... 2,962 2,607 2,663 2,427
-------- ------- ------- -------
Projected benefit obligation............... 12,050 9,104 9,198 8,397
-------- ------- ------- -------
Plan assets less than projected benefit
obligation............................... (12,050) (9,104) (9,198) (8,397)
Unrecognized prior service benefit......... (615) (854) (735) (973)
Unrecognized net loss...................... 2,894 1,088 672 1,031
Additional minimum liability............... (676) (318) (109) (209)
-------- ------- ------- -------
Accrued pension liability recognized in the
consolidated balance sheets.............. $(10,447) $(9,188) $(9,370) $(8,548)
======== ======= ======= =======
</TABLE>
The following significant assumptions were used in computing pension costs
for the Company's defined benefit plans:
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
---------------------- ---------------------------------
1997 1996 1997 1996 1995
--------- ---------- --------- --------- ---------
<S> <C> <C> <C> <C> <C>
Discount Rate............. 8.0%-9.0% 7.8%-9.0% 8.0%-9.0% 8.0%-9.0% 8.0%-9.0%
Increase in future
compensation levels..... 4.5%-7.0% 4.5%-7.0% 4.5%-7.0% 4.5%-7.0% 4.5%-7.0%
Expected long-term rate of
return on assets........ 8.0%-9.0% 8.0%-9.0% 8.0%-9.0% 8.0%-9.0% 8.0%-9.0%
</TABLE>
Other Postretirement Benefits
The Company also provides postretirement medical and life insurance
benefits to all U.S. citizens and certain non-U.S. citizens. The Company's
policy is to fund the cost of these benefits as claims are incurred. The Company
allocates benefit costs to affiliates based on the ratio of active employees of
affiliates to total employees.
F-15
<PAGE> 64
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
The following table sets forth the computation of the accrued liability for
postretirement medical and life insurance benefits (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31, JUNE 30,
----------------- -----------------
1997 1996 1997 1996
------- ------- ------- -------
<S> <C> <C> <C> <C>
Accumulated postretirement benefit obligation:
Retirees...................................... $ 7,809 $ 8,212 $ 8,119 $ 8,126
Fully eligible active participants............ -- 7 7 586
Other active plan participants................ 1,046 919 957 660
------- ------- ------- -------
8,855 9,138 9,083 9,372
Unrecognized net gain........................... 6,027 6,254 6,142 6,315
------- ------- ------- -------
Accrued postretirement benefit cost............. $14,882 $15,392 $15,225 $15,687
======= ======= ======= =======
</TABLE>
Net periodic postretirement benefit cost for these plans includes the
following components (in thousands):
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
---------------- ----------------------------
1997 1996 1997 1996 1995
------ ------ ------- ------- --------
<S> <C> <C> <C> <C> <C>
Service cost............................... $ 29 $ 27 $ 53 $ 57 $ 61
Interest cost.............................. 324 346 691 738 1,090
Amortization of unrecognized gains and
losses................................... (303) (291) (582) (595) (240)
Costs charged to affiliates................ -- -- -- -- (69)
----- ----- ----- ----- ------
Net periodic cost.......................... $ 50 $ 81 $ 162 $ 200 $ 842
===== ===== ===== ===== ======
</TABLE>
The weighted-average annual assumed rate of increase in the per capita cost
of covered medical benefits is 8% for the six months ended December 31, 1997 and
1996 and for the fiscal years ended June 30, 1997, 1996, respectively, and 9%
for the fiscal year ended June 30, 1995. This rate is assumed to decrease to 7%
in 2000, then to 6% in 2005 and remain at that level thereafter. The health care
cost trend rate assumption has a significant effect on the amounts reported. For
example, changing the assumed health care cost trend rates by one percentage
point each year would change the accumulated postretirement benefit obligation
as of December 31, 1997 by approximately $486,000 and the aggregate of the
service and interest cost components of net periodic postretirement benefit cost
for the six months ended December 31, 1997 by approximately $17,000. The
weighted-average discount rate used in determining the accumulated
postretirement benefit obligation was 8% at December 31, 1997 and 1996 and at
June 30, 1997 and 1996.
Annual Incentive Plan
The Company also maintains an Annual Incentive Compensation Plan ("AIP").
The AIP provides for payment of additional compensation to participating
employees, including executive officers, based on individual contributions and
performance measures of the Company as defined in the plan. During the term of
the AIP, an aggregate amount of 286,250 Ordinary Shares will be available for
awards granted wholly or partly in Ordinary Shares under the AIP. Amounts
charged to expense related to awards under the Annual Incentive Compensation
Plan aggregated $1,070,000, $900,000 $2,350,000, $2,600,000 and $2,500,000 for
the six months ended December 31, 1997 and 1996 and for the fiscal years ended
June 30, 1997, 1996 and 1995, respectively.
F-16
<PAGE> 65
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
Performance Unit Plan
The Company's Performance Unit Plan provides incentives to certain members
of management through performance share units to foster and promote the
long-term financial success of the Company. The performance share units vest,
and the related compensation expense is accrued, over a three year performance
period based on performance measures of the Company as defined in the plan.
Amounts charged to expense related to awards under the Performance Unit Plan
aggregated $1,738,000, $2,110,000, $3,370,000, $4,187,000 and $2,500,000 for the
six months ended December 31, 1997 and 1996 and for the fiscal years ended June
30, 1997, 1996 and 1995, respectively. The last awards under the Performance
Unit Plan were granted in December, 1996, and no further awards will be made
under the Plan.
Investment Savings and Profit Sharing Plan
The Company maintains an Investment Savings and Profit Sharing Plan, a
defined contribution 401(k) plan that allows dollar payroll employs to make both
pre-tax and after-tax employee contributions. The Company matches these employee
contributions up to a maximum of 5% of a participant's base salary subject to
the limitations of eligible salary. Employees are vested in all contributions
made. Additionally, although it has not done so since 1984 and currently does
not expect to do so in the future, the Company may also make additional employer
contributions any year out of profits. Matching contributions totaled $843,000,
$739,000, $1,556,000, $1,529,000 and $1,690,000 for the six months ended
December 31, 1997 and 1996 and for the fiscal years ended June 30, 1997, 1996
and 1995, respectively.
1997 Employee Severance Protection Plan
The Company maintains the 1997 Employee Severance Protection Plan (the
"Severance Protection Plan") to retain the services of its employees in the
event of an unsolicited takeover of the Company or in the event of a threat of a
Change of Control, as defined, of the Company. The Severance Protection Plan is
intended to ensure the continued dedication and efforts of the Company's
employees in such events without undue concern for their personal financial and
employment security. The Severance Protection Plan covers all full-time
U.S.-based payroll employees. Severance is only payable in the event of a
termination of employment by the Company other than for "cause" or voluntary
termination by the Employee for "good reason", each as defined in the Severance
Protection Plan, within a specific period following a Change in Control. A
participant will also receive severance if the employee is terminated by the
Company without "cause" or for "good reason" at the request or direction of the
third party involved in the Change in Control or otherwise in connection with or
in anticipation of a Change in Control.
8. SHARE AWARDS AND OPTIONS
1997 Long-term Incentive Plan
The Company has adopted the 1997 Long Term Incentive Plan (the "LTIP"),
which is designed to retain key executives and other selected employees by
rewarding them for making major contributions to the success of the Company and
to provide participants with a proprietary interest in the growth and
performance of the Company.
Employees of the Company eligible for awards under the LTIP are executive
officers, other officers and key management personnel selected by the
Compensation Committee (including employees who are Directors), and whose
performance, in the judgment of the Compensation Committee, can have a
significant effect on the success of the Company. Awards under the LTIP may
consist of the grant of stock options, share appreciation rights, restricted
and/or performance-based share awards and/or restricted and/or performance-based
cash awards, granted singly, in combination or in tandem. The exercise price for
stock options shall
F-17
<PAGE> 66
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
not be less than 85% of the fair market value of the stock on the date of the
option grant (100% in the case of incentive stock options). The Compensation
Committee can also award supplemental payments up to the amount necessary to pay
the federal income tax payable with respect to exercise of nonqualified stock
options, share appreciation rights, restricted shares and performance units. If
approved by the Compensation Committee, the Company may also make loans to
participants to purchase shares pursuant to the exercise of an award. During the
term of the LTIP, an aggregate of 5,725,000 Ordinary Shares will be available
for awards granted wholly or partly in Ordinary Shares under the LTIP. No
participant may receive during a fiscal year incentive awards covering an
aggregate of more than 150,000 Ordinary Shares.
The Company has granted options to purchase an aggregate of 914,600
Ordinary Shares at prices ranging between $28.50 to $45.00 per Ordinary share
and restricted share awards for an aggregate of 246,550 Ordinary Shares under
the LTIP. The options will vest over periods ranging from two to four years and
expire seven to ten years from the date of grant. The restricted share awards
will vest over periods ranging from two to five years from the date of grant.
1997 Employee Share Purchase Plan
The Company has also adopted the 1997 Employee Share Purchase Plan (the
"Share Purchase Plan"), which is designed to furnish eligible employees of the
Company and designated subsidiaries of the Company an incentive to advance the
best interests of the Company by providing a formal program whereby they may
voluntarily purchase Ordinary Shares of the Company at a favorable price and
upon favorable terms. Generally speaking, all covered employees of a
participating company who are scheduled to work an average of at least 20 hours
per week are eligible to participate in the Share Purchase Plan.
Once a year, participants in the Share Purchase Plan will be granted
options to purchase Ordinary Shares with a fair market value equal to the lesser
of 10% of the participant's eligible compensation (as defined in the Share
Purchase Plan) and the amount specified in Section 423(b) of the Code
(currently, $25,000). The exercise price of the options is 85% of the fair
market value of the Ordinary Shares on the date of grant or the date of
exercise, whichever is less. Options granted under the Share Purchase Plan are
exercisable on the date one year after the date of grant. Generally speaking,
participants pay option exercise prices through payroll deductions. An aggregate
of 572,500 Ordinary Shares are available for grants of options under the Share
Purchase Plan. The Share Purchase Plan policy is administered by the
Compensation Committee, which has approved its implementation effective January
1, 1998.
1997 Non-Employee Director Stock Option Plan
The Company has also adopted the 1997 Non-Employee Director Stock Option
Plan (the "Director Plan"). The Director Plan is designed to attract and retain
the services of experienced and knowledgeable non-employee Directors and to
provide non-employee Directors with a proprietary interest in the growth and
performance of the Company. Awards under the Director Plan consist of a grant of
stock options. The purchase price for the shares as to which the option is
exercised will be payable in full upon exercise, in cash or, if permitted by the
Compensation Committee, by tender of Ordinary Shares, valued at "fair market
value." During the term of the Director Plan, an aggregate of 286,250 Ordinary
Shares will be available for awards granted wholly or partly in Ordinary Shares.
No option will be granted under the Director Plan after 10 years following
consummation of the Offering. The Compensation Committee is responsible for
administration and interpretation of the Director Plan.
As of February 28, 1998, the Company had granted options to purchase an
aggregate of 28,000 Ordinary Shares to seven non-employee Directors who
participated in the Director Plan. Such options were granted at exercise prices
ranging from $28.50 to $45.50 per Ordinary Share. Each non-employee Director who
continues in office immediately following the Annual General Shareholders
Meeting in any year (commencing in 1998)
F-18
<PAGE> 67
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
will automatically be granted an option to acquire 2,000 shares of Ordinary
Shares. The Board may increase the number of options granted, provided that a
non-employee Director cannot receive more than 10,000 options in any year. The
price of shares that may be purchased upon exercise of an option is the fair
market value of the Ordinary Shares on the date of the grant. Options granted
pursuant to the Director Plan are exercisable in installments of 33 1/3% upon
each anniversary of the date of grant. The term of each option is for a period
not exceeding 10 years from the date of grant.
The Company applies APB Opinion No. 25, Accounting for Stock Issued to
Employees, in accounting for its plans. Compensation cost charged against income
in connection with stock plans totaled $815,000 for the six months ended
December 31, 1997. The difference between the quoted market price as of the date
of the grant and the purchase price of shares is being charged to operations
over the vesting period. No compensation cost has been recognized for stock
options because the exercise prices of the options equal the market prices of
the underlying stock on the date of the grants.
The following is a summary of all of the Company's share option activity,
and related information for the above plans for the six months ended December
31, 1997 and for the fiscal year ended June 30, 1997:
<TABLE>
<CAPTION>
WEIGHTED AVERAGE
OPTIONS EXERCISE PRICE
------- ----------------
<S> <C> <C>
Outstanding at June 30, 1996............................. -- --
Granted................................................ 291,850 $28.50
Cancelled.............................................. -- --
------- ------
Outstanding at June 30, 1997............................. 291,850 $28.50
------- ------
Granted................................................ 658,550 $45.01
Cancelled.............................................. (7,800) $41.19
------- ------
Outstanding at December 31, 1997......................... 942,600 $39.93
======= ======
</TABLE>
There were no options exercisable at December 31, 1997 and June 30, 1997.
The following table summarizes information about options outstanding at
December 31, 1997:
<TABLE>
<CAPTION>
OPTIONS OUTSTANDING
- ---------------------------------------------------------------------------------------------
WEIGHTED AVERAGE REMAINING
EXERCISE PRICE CONTRACTUAL LIFE(YEARS) NUMBER OF SHARES
-------------- -------------------------- ----------------
<S> <C> <C>
$28.50..................................... 9.44 290,050
$45.50..................................... 9.69 12,000
$45.00..................................... 9.94 640,550
-------
Total............................ 9.69 942,600
=======
</TABLE>
F-19
<PAGE> 68
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
SFAS No. 123, "Accounting for Stock Based Compensation", ("SFAS 123")
requires the disclosure of pro forma net income and earnings per share
information computed as if the Company had accounted for its employee share
options under the fair value method set forth in SFAS 123. The fair value for
these options was estimated at the date of grant using a Black-Scholes option
pricing model with the following weighted-average assumptions:
<TABLE>
<CAPTION>
SIX MONTHS ENDED FISCAL YEAR ENDED
DECEMBER 31, 1997 JUNE 30, 1997
----------------- -----------------
<S> <C> <C>
Expected Life (in years)............................ 3.74 3.63
Risk-free interest rate............................. 6.0% 6.2%
Volatility.......................................... 0.40 0.40
Dividend Yield...................................... 0.46% 0.46%
</TABLE>
The weighted average estimated fair value of options granted during the six
months ended December 31, 1997 and the fiscal year ended June 30, 1997, was
$16.31 and $10.38, respectively. The fair value of these options was estimated
based on an expected life of one year from the vesting date. For purposes of pro
forma disclosures the estimated fair value of stock based compensation plans and
other options is amortized to expense over the vesting period. The Company's pro
forma net income and net income per share is as follows (in thousands except per
share amounts):
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
------------------ ----------------------------
1997 1996 1997 1996 1995
-------- ------- -------- ------- -------
<S> <C> <C> <C> <C> <C>
Net Income
As reported..................... $128,528 $68,658 $164,916 $61,976 $44,298
Pro forma....................... $127,916 $68,658 $164,842 $61,976 $44,298
Earnings per share:
As reported..................... $ 1.12 $ 0.60 $ 1.44 $ 0.54
Pro forma....................... $ 1.11 $ 0.60 $ 1.44 $ 0.54
Diluted earnings per share
As reported..................... $ 1.12 $ 0.60 $ 1.44 $ 0.54
Pro forma....................... $ 1.11 $ 0.60 $ 1.44 $ 0.54
</TABLE>
The effects of applying SFAS 123 for providing pro forma disclosures during
the initial phase-in period may not be representative of the effects on reported
net income for future years.
The Black-Scholes option valuation was developed for use in estimating the
fair value of traded options which have no vesting restrictions and are fully
transferable. In addition, option valuation models require the input of highly
subjective assumptions including the expected share price volatility. Because
the Company's employee share options have characteristics significantly
different from those of traded options, and because changes in the subjective
input assumptions can materially affect the fair value estimate, in management's
opinion, the existing models do not necessarily provide a reliable single
measure of the fair value of its employee share options.
F-20
<PAGE> 69
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
9. EARNINGS PER SHARE
The following table sets forth the computation of basic and diluted
earnings per share (in thousands except share and per share amounts):
<TABLE>
<CAPTION>
SIX MONTHS ENDED DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
----------------------------- ---------------------------
1997 1996 1997 1996
------------- ------------- ------------ ------------
<S> <C> <C> <C> <C>
Numerator:
Net Income................. $ 128,528 $ 68,658 $ 164,916 $ 61,976
Numerator for basic
earnings per
share -- income
available to common
shareholders............ $ 128,528 $ 68,658 $ 164,916 $ 61,976
Denominator:
Denominator for basic
earnings per share --
weighted-average
shares.................. 114,500,000 114,500,000 114,500,000 114,500,000
Effect of dilutive
securities
Employee stock
options............... 108,000 -- 2,000 --
------------ ------------ ------------ ------------
Dilutive potential common
shares.................. 108,000 -- 2,000 --
Denominator for diluted
earnings per share --
adjusted
weighted-average
shares and assumed
conversions........... 114,608,000 114,500,000 114,502,000 114,500,000
============ ============ ============ ============
Basic earnings per share..... $ 1.12 $ 0.60 $ 1.44 $ 0.54
Diluted earnings per share... $ 1.12 $ 0.60 $ 1.44 $ 0.54
</TABLE>
For additional disclosures regarding the employee stock options, see Note
8.
10. COMMITMENTS AND CONTINGENCIES
In the normal course of business, the Company is involved in various
lawsuits, claims and related matters. In the opinion of management, the ultimate
resolution of such matters will not have a material adverse effect on the
consolidated financial position or results of operations of the Company.
In January 1997, the Company entered into a contract for the construction
of the Galaxy II, a heavy duty harsh environment jackup drilling rig. The cost
of the rig, excluding initial mobilization, is expected to be approximately $154
million. The rig is expected to be mobilized in the fourth quarter of 1998. The
Company has entered into a five year drilling contract with a customer for this
rig beginning in October 1998.
In September 1997, the Company entered into a contract for the construction
of the Galaxy III , a heavy duty harsh environment jackup drilling rig. The cost
of the rig, excluding initial mobilization is expected to be approximately $175
million. The rig is expected be mobilized during the fourth quarter of 1999. The
Company has entered into a three year drilling contract with a customer for the
rig to operated in the U.K. sector of the North Sea following initial
mobilization.
F-21
<PAGE> 70
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
11. GEOGRAPHICAL AREA ANALYSIS AND SIGNIFICANT CUSTOMERS
All of the Company's operations are located outside of the Cayman Islands.
The following table summarizes, by geographical area, the identifiable assets of
the Company (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31, JUNE 30,
--------------------- ---------------------
1997 1996 1997 1996
---------- -------- ---------- --------
<S> <C> <C> <C> <C>
North Sea................................ $ 359,411 $359,715 $ 359,347 $406,364
North Africa............................. 136,760 109,207 97,660 105,689
West Africa.............................. 66,830 59,509 62,797 17,885
Southeast Asia and Pacific............... 62,876 85,443 105,125 56,684
Middle East and Azerbaijan............... 153,095 93,728 146,094 94,406
South America............................ 42,471 30,277 44,561 24,652
North America............................ 108,011 95,274 89,471 97,017
Corporate assets(1)...................... 231,999 115,079 95,391 82,301
---------- -------- ---------- --------
Total assets................... $1,161,453 $948,232 $1,000,446 $884,998
========== ======== ========== ========
</TABLE>
- ---------------
(1) Consists primarily of cash equivalents, marketable securities, construction
in progress, and other corporate assets.
The following table summarizes, by geographical area, operating revenues
and operating income (loss) (in thousands):
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
------------------- ------------------------------
1997 1996 1997 1996 1995
-------- -------- -------- -------- --------
<S> <C> <C> <C> <C> <C>
Operating revenues
North Sea....................... $135,201 $103,298 $219,466 $196,784 $196,047
North Africa.................... 62,191 52,793 107,979 98,423 95,692
West Africa..................... 35,476 17,552 48,263 16,520 11,002
Southeast Asia and Pacific...... 36,131 18,304 49,585 37,347 55,734
Middle East and Azerbaijan...... 66,160 44,971 93,988 89,786 91,129
South America................... 24,446 19,502 43,098 20,647 16,419
North America................... 15,580 8,371 16,184 11,375 239
-------- -------- -------- -------- --------
Total revenues.......... $375,185 $264,791 $578,563 $470,882 $466,262
======== ======== ======== ======== ========
Operating income (loss)
North Sea....................... $ 64,210 $ 43,074 $ 95,448 $ 51,084 $ 25,842
North Africa.................... 32,358 23,196 49,212 26,031 16,835
West Africa..................... 20,757 5,573 22,261 3,968 2,344
Southeast Asia and Pacific...... 14,091 (2,898) 5,998 654 5,418
Middle East and Azerbaijan...... 17,451 9,297 20,446 6,684 11,027
South America................... 2,867 3,077 7,429 1,378 2,506
North America................... 3,668 1,109 (3,421) (3,010) (2,794)
Corporate expenses.............. (11,178) (7,960) (17,725) (17,962) (17,019)
-------- -------- -------- -------- --------
Total operating
income................ $144,224 $ 74,468 $179,648 $ 68,827 $ 44,159
======== ======== ======== ======== ========
</TABLE>
F-22
<PAGE> 71
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
Operating income consists of operating revenues less operating expenses,
including depreciation, and does not include interest income, other income,
interest expense and income taxes.
The Company's operations in the North Sea are presently all conducted
within the U.K. sector of the North Sea. The Company's operations in North
Africa consist principally of operations in Egypt. The Company's operations in
the Middle East include significant operations in Kuwait. See Note 12.
A substantial portion of the Company's assets are mobile. Asset locations
at the end of the period are not necessarily indicative of the geographic
distribution of the earnings generated by such assets during the periods.
General corporate assets are principally cash and cash equivalents and other
nonoperating assets.
The Company's operations are geographically dispersed and are therefore
subject to certain political and other uncertainties not encountered in domestic
operations, including risks of war, expropriation of equipment, renegotiation or
modification of existing contracts, taxation policies, and the general hazards
associated with foreign sovereignty over certain areas in which operations are
conducted.
Operational risks and hazards may result in extensive damage to or total
loss of drilling rigs, with associated personal injuries and loss of life,
pollution, well loss, well control expenses and/or wreck removal or other
requirements. Such losses, liabilities or obligations may be uninsured or
underinsured. In the event of a major incident or incidents resulting from
operational risks and hazards, the Company will sustain a loss of revenue by
reason of the rig loss or damage and may be subject to significant additional
expenses in respect of uninsured or underinsured losses, liabilities or
obligations.
The following table summarizes revenues from major customers of the Company
as a percentage of total operating revenues for the period indicated.
<TABLE>
<CAPTION>
SIX MONTHS ENDED
DECEMBER 31, FISCAL YEAR ENDED JUNE 30,
---------------- --------------------------
1997 1996 1997 1996 1995
------ ------ ------ ------ ------
<S> <C> <C> <C> <C> <C>
Shell............................................ 13.9% 6.9% 9.3% 18.3% 22.6%
British Petroleum................................ 8.6% 15.9% 14.0% 12.0% 8.8%
British Gas...................................... 7.5% 4.4% 7.6% 6.0% 4.0%
AGIP............................................. 6.4% 8.0% 7.0% 9.5% 8.1%
ELF Aquitaine.................................... 5.5% 0.0% 1.9% 0.0% 0.0%
Texaco........................................... 5.3% 7.3% 6.4% 2.2% 2.1%
Kuwait Oil Company (Note 12)..................... 4.6% 4.8% 4.4% 7.6% 11.5%
Corpoven......................................... 4.0% 5.8% 5.3% 3.5% 2.4%
Amoco............................................ 1.1% 7.5% 5.2% 3.2% 2.1%
Phillips Petroleum Company....................... 0.0% 5.5% 3.9% 10.3% 7.5%
</TABLE>
12. TRANSACTIONS WITH AFFILIATES
The Company provides contract drilling services in Kuwait to the Kuwait Oil
Company, K.S.C. ("KOC"), a subsidiary of KPC, and also provides contract
drilling services to a partially owned affiliate of KOC in the Kuwait-Saudi
Arabian Partitioned Neutral Zone. Such services are performed pursuant to
drilling contracts which contain terms and conditions and rates of compensation
which materially approximate those which are customarily included in
arm's-length contracts of a similar nature. In connection therewith, KOC
provides the Company rent free use of certain land and maintenance facilities
and has committed to continue providing same, subject to availability of the
maintenance facilities, through the current February 2001 term of the drilling
contracts. In relation to its drilling business in Kuwait, the Company has an
agency agreement with a subsidiary of KPC which obligates the Company to pay an
agency fee based on a percentage of revenues. The Company believes the terms of
this agreement are more favorable than those which could be
F-23
<PAGE> 72
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
obtained with an unrelated third party in an arm's-length negotiation, but the
value of such terms is currently immaterial to the Company's results of
operations.
The Company earned revenues from KPC affiliated companies in the ordinary
course of business of $17,315,000, $12,765,000, $25,268,000, $35,925,000 and
$53,570,000 for the six months ended December 31, 1997 and 1996 and for the
fiscal years ended June 30, 1997, 1996 and 1995, respectively. The Company paid
agency fees to a subsidiary of KPC of $175,038, $159,960, $259,827, $356,851 and
$546,846 during the six months ended December 31, 1997 and 1996 and for the
fiscal years ended June 30, 1997, 1996 and 1995, respectively. The Company had
accounts receivable from KPC affiliated companies of $5,597,000, $2,337,000,
$2,127,000 and $3,707,000 at December 31, 1997 and 1996 and June 30, 1997 and
1996, respectively.
In connection with the Reorganization, the Company made distributions to
Holdings during the three years ended June 30, 1997 comprised principally of
certain subsidiaries which conducted the Company's former non-drilling
operations and services (the "Non-Drilling Subsidiaries") and certain additional
non-drilling assets, including real estate, cash and cash equivalents.
The Company, Holdings and KPC entered into an Intercompany Agreement before
the consummation of the Offering (the "Intercompany Agreement"), certain
provisions of which are summarized below. As used herein, "KPC Affiliated Group"
means KPC and its affiliates, including Holdings, other than the Company and its
subsidiaries.
As of December 31, 1997, the consolidated financial statements of Holdings
contained liabilities to third parties, including tax liabilities, aggregating
approximately $66 million incurred by the Non-Drilling Subsidiaries on or before
March 31, 1997. As of December 31, 1997, Holdings maintained cash and cash
equivalents (the "Liability Payment Fund") sufficient to satisfy those
liabilities remaining after such date. The Company, Holdings and KPC have agreed
in the Intercompany Agreement that all amounts paid to claimants to satisfy
those liabilities, whether by settlement, judgment or award (including
claimants' attorneys' fees), will be paid by Holdings from the Liability Payment
Fund. The Company will pay all internal and external costs and fees (including
the Company's and Holdings' attorneys' fees) associated with management and
resolution of those liabilities, and believes such costs and fees will not be
material. If any amount remains in the Liability Payment Fund at March 31, 2002,
Holdings will pay the Company the first $10 million of such amount and 50% of
any amount in excess of $10 million. Thereafter, or if the resolution of those
liabilities earlier exhausts the Liability Payment Fund, Holdings will have no
further responsibility for those liabilities, and the Company will be
responsible for all costs, fees and amounts paid to resolve those liabilities
and will indemnify the KPC Affiliated Group in respect of such costs and fees
and those liabilities. The Company believes that the Liability Payment Fund is
adequate to provide for such costs and fees and those liabilities. Accordingly,
the Company believes that the indemnification costs, if any, will not be
material and no additional reserves have been established by the Company in
respect of such costs and fees and those liabilities or the Company's obligation
under the Intercompany Agreement relating to such costs and fees and those
liabilities.
The Intercompany Agreement also provides that, except as may be provided in
a separate agreement, the Company will indemnify the KPC Affiliated Group
against losses based on, or taxes arising from, the following: (i) the ownership
of the assets or the operation of the business of the Company or its
subsidiaries, (ii) any other activities of the Company or its subsidiaries,
(iii) any guaranty or similar agreement by the KPC Affiliated Group provided to
any person with respect to any obligation of the Company or its subsidiaries,
and (iv) certain other matters. In addition, the Company has agreed to indemnify
the KPC Affiliated Group against certain civil liabilities, including
liabilities under the Securities Act of 1933, as amended ("the Securities Act"),
relating to misstatements in or omissions from any registration statement or
report that the Company files under the Securities Act. Holdings has also agreed
to indemnify the Company and its subsidiaries against losses based on the
ownership or operation of the assets or properties or the operation or conduct
of the business of Holdings and its subsidiaries on or after March 31, 1997.
F-24
<PAGE> 73
SANTA FE INTERNATIONAL CORPORATION AND SUBSIDIARY COMPANIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
DECEMBER 31, 1997
The Company also entered into a Management Services Agreement with Holdings
(the "Management Services Agreement"), for the purpose of providing asset
(primarily real estate) management services, general and administrative services
and liability management and resolution services to Holdings, the Non-Drilling
Subsidiaries and inactive subsidiaries of Holdings. The Management Services
Agreement authorizes the Company to resolve the liabilities of the Non-Drilling
Subsidiaries under the Intercompany Agreement using the Liability Payment Fund.
Although Holdings retains the right to reduce or expand the scope of services to
be performed by the Company pursuant to the Management Services Agreement, the
Company's liability management and resolution service may not be reduced or
terminated. The Management Services Agreement also provides for payment of an
initial asset management fee to the Company of $173,000 per year as well as
reimbursement of out-of-pocket costs in respect of asset management services,
and stipulates that the fees are subject to negotiation on an annual basis and
upon any reduction in or expansion of the scope of services provided by the
Company. The Company will pay all internal and external costs and fees
(including the Company's and Holdings' attorney's fees) associated with the
Company's liability management and resolution services and all internal and
external costs and fees associated with the provision of general and
administrative services pursuant to the Management Services Agreement. The
Company believes such costs and fees will not be material.
13. QUARTERLY RESULTS (UNAUDITED)
Shown below are selected unaudited quarterly data (in thousands), except
per share data:
<TABLE>
<CAPTION>
THREE MONTHS ENDED
------------------------------------------------
SEPTEMBER 30 DECEMBER 31 MARCH 31 JUNE 30
------------ ----------- -------- --------
<S> <C> <C> <C> <C>
SIX MONTHS ENDED DECEMBER 31, 1997
Operating revenues............................. $176,787 $198,398
======== ========
Operating income............................... $ 67,058 $ 77,166
======== ========
Net income..................................... $ 59,322 $ 69,206
======== ========
Basic and Diluted Income per Ordinary Share.... $ 0.52 $ 0.60
======== ========
FISCAL YEAR ENDED JUNE 30, 1997
Operating revenues............................. $126,080 $138,711 $149,253 $164,519
======== ======== ======== ========
Operating income............................... $ 34,782 $ 39,686 $ 47,134 $ 58,046
======== ======== ======== ========
Net income..................................... $ 30,994 $ 37,664 $ 42,923 $ 53,335
======== ======== ======== ========
Basic and Diluted Income per Ordinary Share.... $ 0.27 $ 0.33 $ 0.37 $ 0.47
======== ======== ======== ========
FISCAL YEAR ENDED JUNE 30, 1996
Operating revenues............................. $111,255 $114,529 $118,417 $126,681
======== ======== ======== ========
Operating income............................... $ 9,489 $ 15,925 $ 21,722 $ 21,691
======== ======== ======== ========
Net income..................................... $ 9,012 $ 14,067 $ 17,393 $ 21,504
======== ======== ======== ========
Pro forma basic and diluted net income per
ordinary share............................... $ 0.08 $ 0.12 $ 0.15 $ 0.19
======== ======== ======== ========
FISCAL YEAR ENDED JUNE 30, 1995
Operating revenues............................. $110,963 $120,339 $109,590 $125,370
======== ======== ======== ========
Operating income............................... $ 10,003 $ 10,400 $ 12,969 $ 10,787
======== ======== ======== ========
Net income..................................... $ 7,342 $ 8,731 $ 9,571 $ 18,654
======== ======== ======== ========
</TABLE>
F-25
<PAGE> 74
SIGNATURES
Pursuant to the requirements of Section 12 of the Securities Exchange Act
of 1934, the Registrant certifies that it has reasonable grounds to believe that
it meets all of the requirements for filing on Form 20-F and has duly caused
this transition report to be signed on its behalf by the undersigned, thereunto
duly authorized.
SANTA FE INTERNATIONAL CORPORATION
By: /s/ D.G. BARBER
----------------------------------
D.G. Barber, Senior Vice President
and Chief Financial Officer
Date: March 26, 1998
<PAGE> 75
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT DESCRIPTION
------- -----------
<C> <S>
*1 -- U.S. and International Underwriting Agreements among the
Registrant and the various Underwriters, dated June 9,
1997.
**3.1 -- Amended and Restated Memorandum of Association of the
Registrant.
**3.2 -- Amended and Restated Articles of Association of the
Registrant.
*4 -- Specimen of Ordinary Shares Certificate.
**10.1 -- Registrant's Investment Savings and Profit Sharing Plan.
**10.2 -- Registrant's Pension Plan (U.S. employees).
**10.3 -- Registrant's Special Pension Plan (non-U.S. employees).
**10.4 -- Registrant's Equity Restoration Plan.
*10.5 -- Registrant's Supplemental Executive Retirement Plan.
*10.6 -- Registrant's Performance Unit Plan.
***10.7 -- Registrant's Annual Incentive Compensation Plan.
***10.8 -- Registrant's 1997 Long Term Incentive Plan.
***10.9 -- Registrant's 1997 Non-Employee Director Stock Option
Plan.
***10.10 -- Registrant's 1997 Employee Share Purchase Plan.
*10.11 -- Registrant's Employee Severance Protection Plan.
*10.12 -- Registrant's Directors and Officers Indemnity Agreement.
*10.13 -- Intercompany Agreement by and among Kuwait Petroleum
Corporation, SFIC Holdings (Cayman), Inc. and the
Registrant, dated June 9, 1997.
*10.14 -- Management Services Agreement by and between SFIC
Holdings (Cayman), Inc. and the Registrant, dated June 9,
1997.
**10.15 -- Agency Agreement between Kuwait Santa Fe Braun for
Engineering and Petroleum Enterprises (K.S.B.) Company
K.S.C. and the Registrant, dated April 1, 1992.
**10.16 -- Contract for the Construction and Sale of a Jackup
Drilling Unit by and between Far East Levingston
Shipbuilding Ltd. and the Registrant dated as of December
16, 1996.
**10.17 -- Drilling Contract by and between Mobil Oil Canada
Properties and Santa Fe Drilling Company (Canada)
Limited, dated as of December 16, 1996.
*10.18 -- Share Purchase Agreement between SFIC Holdings (Cayman)
Inc. and the Registrant, dated as of June 9, 1997.
*10.19 -- Contract for the Construction and Sale of Jackup Drilling
Unit Galaxy III by and between Keppel FELS Limited and
the Registrant, dated as of September 17, 1997.
*10.20 -- Letter of Interim Agreement for Provision of Jackup
Drilling Unit by and between Amoco (U.K.) Exploration
Company and the Registrant, dated as of September 3,
1997.
****10.21 -- Consulting Agreement dated December 10, 1997 between
Registrant and Gordon M. Anderson.
****10.22 -- AMOCO (U.K.) Exploration Company Form of Contract Ref:
AD3300 for The Provision of the Jack-Up Drilling Unit
Santa Fe "Galaxy III" for Drilling Operations on the
U.K.C.S. with Santa Fe Drilling Company (North Sea)
Limited, Dated September 3, 1997 (with Appendix 5 only).
**21 -- List of Subsidiaries
23.1 -- Consent of Ernst & Young LLP, independent auditors
</TABLE>
- ---------------
* Incorporated by reference to the Company's Annual Report on Form 20-F for
the fiscal year ended June 30, 1997.
** Incorporated by reference to the Company's Registration Statement on Form
F-1 (No. 333-6912) filed May 14, 1997.
*** Incorporated by reference to the Company's Registration Statement on Form
S-8 (No. 333-7070) filed June 13, 1997.
**** Incorporated by reference to the Company's Report on Form 6-K filed March
3, 1998.
<PAGE> 1
EXHIBIT 23.1
CONSENT OF INDEPENDENT AUDITORS
We consent to the incorporation by reference in the Registration Statement
(Form S-8 No. 333-7070) of Santa Fe International Corporation of our report
dated January 28, 1998, with respect to the consolidated financial statements of
Santa Fe International Corporation included in this Annual Report (Form 20-F)
for the transition period from July 1, 1997 to December 31, 1997.
ERNST & YOUNG LLP
Dallas, Texas
March 26, 1998
