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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
----------------------
1998 FORM 10-K
(MARK ONE)
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934. (NO FEE REQUIRED)
FOR THE FISCAL YEAR ENDED DECEMBER 31, 1998
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934. (NO FEE REQUIRED)
FOR THE TRANSITION PERIOD FROM ___________ TO ____________.
COMMISSION FILE NUMBER: 0-18309
MARINE DRILLING COMPANIES, INC.
(Exact name of registrant as specified in its charter)
TEXAS 74-2558926
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification Number)
ONE SUGAR CREEK CENTER BLVD., SUITE 600, SUGAR LAND, TEXAS 77478-3556
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (281) 243-3000
Securities registered pursuant to Section 12(b) of the Act:
NONE
Securities registered pursuant to Section 12(g) of the Act:
Name of each exchange
Title of each class on which registered
------------------- ----------------------
COMMON STOCK, $.01 PAR VALUE NEW YORK STOCK EXCHANGE
PREFERRED SHARE PURCHASE RIGHTS NEW YORK STOCK EXCHANGE
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes [X] No [ ].
Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. [X]
AGGREGATE MARKET VALUE OF THE COMMON STOCK HELD BY
NONAFFILIATES ON MARCH 10, 1999 -- $448,365,740
NUMBER OF SHARES OF COMMON STOCK OUTSTANDING
ON MARCH 10, 1999, - 52,434,634
DOCUMENTS INCORPORATED BY REFERENCE
(1) Certain portions of the Proxy Statement for Annual Meeting of Shareholders
to be held May 13, 1999 - Part III
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MARINE DRILLING COMPANIES, INC.
1998 FORM 10-K
TABLE OF CONTENTS
<TABLE>
<CAPTION>
Page
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PART I
<S> <C> <C>
Item 1. Business................................................................................................ 1
Item 2. Properties.............................................................................................. 10
Item 3. Legal Proceedings....................................................................................... 13
Item 4. Submission of Matters to a Vote of Security Holders..................................................... 13
PART II
Item 5. Market for Registrant's Common Stock and Related Shareholder Matters.................................. 14
Item 6. Selected Consolidated Financial Data.................................................................... 15
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations................... 16
Item 7A. Quantitative and Qualitative Disclosures about Market Risk.............................................. 23
Item 8. Financial Statements and Supplementary Data............................................................. 24
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.................... 42
PART III
Item 10. Directors and Executive Officers of the Registrant...................................................... 42
Item 11. Executive Compensation.................................................................................. 42
Item 12. Security Ownership of Certain Beneficial Owners and Management.......................................... 42
Item 13. Certain Relationships and Related Transactions.......................................................... 42
PART IV
Item 14. Exhibits and Reports on Form 8-K........................................................................ 42
Signatures......................................................................................................... 44
</TABLE>
(i)
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PART 1
ITEM 1. BUSINESS
GENERAL
Marine Drilling Companies, Inc. (collectively with its subsidiaries,
the "Company") was incorporated in Texas in January 1990. Since 1966, the
Company or its predecessors have been engaged in offshore contract drilling of
oil and gas wells for independent and major oil and gas companies. Operations
are conducted in the U.S. Gulf of Mexico and internationally. The Company's
principal office is located at One Sugar Creek Center Blvd., Suite 600, Sugar
Land, Texas 77478 and its telephone number is (281) 243-3000.
The Company owns and operates a fleet of 17 offshore drilling rigs
consisting of six independent leg jack-up units, three of which have a
cantilever feature, nine mat supported jack-up units, four of which have a
cantilever feature and two semi-submersible units. The Company also operates one
additional semi-submersible drilling rig under a five-year bareboat charter
agreement (the "Charter"). Currently twelve of the Company's rigs are located in
the U.S. Gulf of Mexico, one rig is in the Middle East, two rigs are in
Southeast Asia, one rig is in the North Sea, one rig is being upgraded in
Southeast Asia and one rig is under construction in the U.
S. Gulf of Mexico.
BUSINESS STRATEGY
The Company's business strategy is designed to position it to
capitalize on cyclical upturns, and minimize exposure to cyclical downturns, in
the worldwide jack-up rig market. The key elements of this strategy are:
o U.S. Gulf of Mexico Jack-up Rig Fleet Focus. The Company is
committed to remaining a leading operator of jack-up rigs in
the U.S. Gulf of Mexico. The Company believes that its
significant presence in the region offers logistical
advantages, including reduced mobilization costs and
flexibility of crew deployment, both of which reduce operating
costs. The Company also believes that, if oil and gas prices
recover from their currently depressed levels, there is
significant upside potential for dayrates in the U.S. Gulf of
Mexico jack-up rig market due to both a worldwide supply of
jack-up rigs that is not growing and an increasing rate of oil
and natural gas reserve depletion in the region, which could
increase drilling activity.
o Maintain an Appropriate Capital Structure. Because the
offshore drilling business is subject to substantial
fluctuations in demand, pricing and profitability, the Company
seeks to maintain a level of debt that can be adequately
supported by its working capital and long-term contract
revenues. The Company believes this approach will enable it to
better withstand the volatility associated with industry
cycles.
o Balanced Long-Term and Short-Term Contract Portfolio. The
Company seeks to appropriately balance its contract portfolio
between long-term and short-term contracts. The Company
believes that a balanced contract portfolio will help mitigate
the cyclical nature of the drilling industry and will provide
for a component of longer-term, more predictable cash flow,
while maintaining the opportunity to capitalize on potential
increases in drilling rig dayrates worldwide. In the current
market environment, availability of long-term contracts has
been primarily limited to semi-submersible rigs used for
offshore drilling in deepwater markets. To capitalize on the
long-term contracts available in this market, the company is
in the process of completing the construction and upgrade of
two semi-submersible rigs, the MARINE 700 and the MARINE 500,
for use in deepwater drilling operations. The Company has
entered into long-term contracts to operate both of these
rigs, which it expects will generate contract revenues of
approximately $452 million over the life of the contracts. The
Company believes that these two contracts will help to
counterbalance the short-term and spot market contract portion
of its rig portfolio.
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o Growth Through Acquisitions and Upgrades. The Company is
actively seeking attractive opportunities for acquisitions to
increase the size and capabilities of its fleet. The Company
believes that a prolonged period of depressed industry
fundamentals may result in assets becoming available at
attractive prices. Additionally, when market conditions
warrant, the Company may elect to perform upgrades on its
existing rig fleet.
To further the Company's business strategy, it has recently undertaken
two significant rig construction and upgrade projects, the MARINE 700 and the
MARINE 500.
The MARINE 700. In May 1997, the Company acquired the uncompleted hull
for the MARINE 700 for approximately $55 million to serve as the foundation for
a fourth-generation semi-submersible rig with 5,000-foot water depth drilling
capacity. In December 1997, the Company entered into a shipyard contract with
HAM Marine, Inc. ("HAM") under which HAM would complete construction of the
MARINE 700. The shipyard contract calls for HAM to fabricate certain components
of the rig and install certain owner furnished equipment ("OFE"). The Company
currently estimates that the OFE will cost approximately $112 million, including
capitalized interest and project management costs, and that shipyard costs will
total an additional $103 million, resulting in a total estimated cost to
complete the drilling rig of $215 million (exclusive of the $55 million hull
purchase cost). Through December 31, 1998 the Company has paid HAM approximately
$60 million in progress payments and incurred approximately $70 million for OFE
and other related construction costs. The Company currently believes that the
rig will be completed late in the second quarter of 1999, after which it will
begin work for Esso Exploration Inc. ("Esso"), an affiliate of Exxon Corporation
under a five year contract initially in its Diana field Project, a major
deepwater project in the U.S. Gulf of Mexico. See "Contracts-MARINE 700 Drilling
and Construction Contracts," "Construction and Contract Risks," Management's
Discussion and Analysis of Financial Condition and Results of
Operations-Financial Condition-Liquidity and Capital Resources."
The MARINE 500. In December 1996, the Company acquired the MARINE 500,
a second-generation semi-submersible rig, for approximately $38 million. In
December 1997, the Company signed a contract with Jurong Shipyard Limited
("Jurong") in Singapore to upgrade the MARINE 500 to fourth-generation
capabilities. The shipyard contract calls for Jurong to fabricate certain
components of the rig and to install certain OFE. The Company currently
estimates that the OFE will cost approximately $72 million, including
capitalized interest and project management costs, and that payments to the
shipyard under the contract will be approximately $48 million, resulting in a
total estimated cost to complete the drilling rig of $120 million (exclusive of
the $38 million acquisition cost). Through December 31, 1998, the Company has
paid Jurong approximately $8 million in progress payments and incurred
approximately $49 million for OFE and other related construction costs.
Currently the Company believes that the rig will be completed during the second
quarter of 1999, after which it will begin work in Western Australia for WAPET,
an entity owned by several major integrated oil companies. See "Contracts-MARINE
500 Drilling and Construction Contracts," "Construction and Contract Risks,"
Management's Discussion and Analysis of Financial Condition and Results of
Operations-Financial Condition-Liquidity and Capital Resources."
The following table summarizes certain terms of the drilling contracts
for the MARINE 700 and the MARINE 500 projects:
<TABLE>
<CAPTION>
ESTIMATED
CONTRACTUAL
RIG CUSTOMER CONTRACT TERM BASE DAYRATE (1) REVENUE (2)
----------------- ------------------------ ---------------------- ------------------ ---------------
<S> <C> <C> <C> <C>
MARINE 700 Esso 5 Years $ 165,410 $298 million
MARINE 500 WAPET; INPEX (3) Until Dec. 31, 2001 $127,500-168,000 $154 million
</TABLE>
(1) See "Business - Contracts" for a discussion of contracts and related
dayrates.
(2) Assumes full utilization at the normal operating base dayrate for 360 days
per year for the contract term.
(3) Indonesia Petroleum, Ltd.
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CURRENT ADVERSE MARKET CONDITIONS
Oil and gas prices have reached multi-year lows in various markets in
recent months. As a result, oil and gas companies have made significant cutbacks
in their drilling programs. This has reduced industry-wide rig utilization
including the U.S. Gulf of Mexico, where the Company operates most of its rigs,
which has not only sharply reduced dayrates, but also shortened the average
length of drilling contracts. In addition, long-term contracts for a number of
rigs owned by other contractors have recently been canceled, for varied reasons,
by their customers.
The following table sets forth current rig utilization rates and
average utilization rates for 1998, 1997 and 1996, according to Offshore Data
Services:
<TABLE>
<CAPTION>
AS OF
MARCH 9, 1999 1998 1997 1996
-------------------- -------------------- -------------------- --------------------
<S> <C> <C> <C> <C>
Gulf of Mexico jack-up rigs 59% 81% 90% 87%
Worldwide jack-up rigs 67% 83% 89% 86%
Worldwide semi-submersible rigs 63% 78% 81% 79%
</TABLE>
As of March 10, 1999, nine of the Company's 15 jack-up rigs are
committed under short-term contracts that will expire in the first or second
quarter of 1999, one rig is under contract for one year, and the remaining 5
rigs are idle. All of the currently committed rigs are in the U.S. Gulf of
Mexico. The Company currently has no international rigs working. The current
market conditions will adversely affect the Company's results of operations for
at least the near term, substantially reducing its revenues, cash flows and
earnings and likely resulting in losses in 1999 until the MARINE 700 and the
MARINE 500 begin operations. Oil and gas prices may continue to deteriorate, and
the Company cannot predict whether or when they might recover.
CONTRACTS
General. The Company's drilling contracts generally provide for
compensation on a "daywork" basis. Under daywork contracts, the Company receives
a fixed amount per day for providing drilling services using the rigs it
operates. Under most daywork contracts, the Company pays virtually all costs
associated with operating the rig such as labor, operating supplies and repair
and maintenance. The Company typically negotiates with the customer the cost of
moving the rigs and related equipment to the job site and the customer pays all
other costs of drilling the well such as mud, casing, logging and completion
services. Daywork contracts may provide for lower rates during periods when
drilling operations are interrupted or restricted by equipment breakdowns,
adverse weather or water conditions or other conditions beyond the Company's
control. Historically, the Company has not marketed its rigs under fixed price
or turnkey contracts.
A daywork contract generally extends over a period of time covering
either the drilling of a single well, a group of wells or a stated term. The
customer may terminate the contract if the drilling rig is destroyed or lost, or
if drilling operations are suspended for a specified period of time as a result
of breakdown of major equipment or other specific events. The duration of
drilling contracts is generally determined by market demand and competitive
conditions. Historically, domestic drilling contracts are typically on a
well-by-well basis, while contracts in the deepwater and international jack-up
markets have been on a term basis. The Company's experience during recent years
has been consistent with this general rule, with its rigs operating in the Gulf
of Mexico generally having been contracted on a well-to-well basis and its rigs
operating internationally operating under term contracts. Due to the highly
cyclical nature of the offshore drilling business, to the extent available, the
Company will continue to focus on obtaining additional term contracts, both
foreign and domestic, in the future. Such contracts help mitigate the volatility
of the Company's results.
The Company obtained most of its contracts through competitive bidding
against other contractors in response to oil and gas companies' solicitations of
bids. The Company's current drilling contracts, both foreign and domestic,
provide for payment in U.S. Dollars.
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MARINE 700 Drilling and Construction Contracts. In January 1998, the
Company signed a long-term drilling contract with Esso for the MARINE 700. The
contract had an initial term of three years and gave Esso the option to extend
the contract to a five-year term. In June 1998, Esso exercised the option to
extend the contract to five years, with a normal operating dayrate of $165,410
per day ($159,910 per day during moving and standby and $136,650 per day during
force majeure events). In addition to the normal operating dayrate, the Company
will be entitled to obtain approximately $4,600 per day cost recovery for
certain construction and equipment changes requested by Esso during the
construction process. The dayrates are also subject to adjustments for changes
in indexed operating cost elements, changes in costs arising from moving the rig
outside the U.S. Gulf of Mexico, or changes in personnel requirements. The Esso
contract is expected to generate aggregate dayrate revenues of approximately
$298 million, not including the additional construction cost recoveries. The
contract also entitles Esso to elect up to five additional one-year extensions
of the primary term at mutually agreeable dayrates.
The contract permits Esso to terminate the contract prior to the end of
the five-year term in the following circumstances:
o if the rig is not completed in accordance with contract
specifications and ready to depart the shipyard to the first
well location by July 15, 1999, other than as a result of
delays caused by Esso or its subcontractors,
o if the design, construction or operation of the rig is not in
accordance with reasonable performance standards or if, in
Esso's opinion, the Company makes unreasonably slow progress
in the drilling work, and fails to remedy these problems
within a reasonable time after written notice,
o if the rig is unsuitable, if the available deckload is less
than 90% of the stated capacity, or if marine or drilling
equipment is below manufacturer's specifications, in each case
if such deficiencies cannot be corrected within 30 days, or
o in the event of certain other breaches of the contract by the
Company relating to pollution control obligations and labor
policies.
In addition, either party may terminate the contract in the event of
the occurrence or anticipation of a 60 day force majeure event, which means
labor disturbances, riots, war, acts of government or military agencies, fires,
floods, earthquakes and any other cause beyond the reasonable control of the
affected party that could not, with reasonable diligence, have been prevented or
provided against, but excluding financial distress.
In May 1997, the Company acquired the uncompleted hull for the MARINE
700 for approximately $55 million. In December 1997, the Company entered into an
agreement with HAM under which HAM would complete construction of the MARINE 700
semi-submersible drilling rig in their shipyard in Pascagoula, Mississippi for
$87 million. The shipyard contract calls for HAM to fabricate certain components
of the rig and install certain OFE. The shipyard contract calls for monthly
progress payments based on the percentage of completion. The Company originally
estimated that the OFE would cost approximately $99 million including
capitalized interest and project management costs resulting in a total estimated
cost to complete the drilling rig of $186 million (exclusive of the $55 million
hull acquisition cost). Construction of the rig has progressed since the signing
of the shipyard contract and through December 31, 1998, the Company has paid HAM
approximately $60 million in progress payments and paid approximately $70
million for OFE and other related construction costs.
The shipyard contract initially contemplated a delivery date of
February 17, 1999. However, due to engineering, construction, weather and other
delays, the Company now expects to complete construction of the MARINE 700 late
in the second quarter of 1999. Additionally, the anticipated construction and
outfitting cost has increased to approximately $215 million. Included in the $29
million increase over the original cost estimate is the cost of change orders
initiated by Esso, the Company's customer. Current estimates for the cost of
these change orders is approximately $5.7 million, which the Company will
recover through an increase in the dayrate during the term of the five-year
drilling contract of approximately $4,600 per day. See "Construction and
Contract Risks" for discussion of risks associated with the MARINE 700
contracts.
MARINE 500 Drilling and Construction Contracts. In July 1997, the
Company entered into a drilling contract with a drilling consortium led by WAPET
for the MARINE 500. The consortium consists of WAPET, Indonesia Petroleum, Ltd.
("INPEX") and Mobil Exploration and Producing Australia ("MEPA"). Certain other
oil companies
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have an option to participate in the consortium. The contract requires the
Company, prior to delivery of the rig, to upgrade the rig to work in water
depths up to 5,000 feet with 15,000 psi drilling equipment, as described below.
The contract was originally scheduled for a three-year term beginning in January
1999. However, because the rig was delayed in arriving at the shipyard for the
upgrade work as a result of work extensions for its previous customer, the
Company does not expect the rig to be available to commence drilling until the
second quarter of 1999. This delay, however, did not extend the term of the
contract, so the contract will still expire on December 31, 2001. During the
term of this contract, the MARINE 500 will work predominately in Western
Australia, although the contract entitles the consortium members to use the rig
in Southeast Asia, the Pacific Rim, and New Zealand.
The consortium drilling contract is a master agreement that
contemplates separate drilling contracts with the individual consortium members
at a base dayrate of $127,500, which is adjusted for each contract based on
operating costs in the area in which the rig is to be used. Two of the
consortium members, WAPET and INPEX, have committed drilling contracts under the
consortium agreement and have agreed under the consortium agreement to be liable
for the contract minimum payments to the Company for the initial contract term
ending December 31, 2001. The optional consortium members have made no
commitments under the agreement, and are not liable for any payments under the
consortium contract until they commit to a drilling contract. The INPEX drilling
contract is a two-well contract with up to three option wells to be drilled at
an operating dayrate of $150,000 per day. The WAPET drilling contract provides
for a dayrate of $168,600 for an unspecified number of wells. Under the
contract, a mobilization rate of $166,240, or 98.6% of the operating dayrate,
will begin when the rig leaves the shipyard in Singapore, at which time the
Company will also be entitled under the consortium drilling contract to receive
an upfront mobilization fee of $6 million. The contract provides that the
consortium can terminate the contract at any time after January 1, 2001 in
exchange for a termination payment of $95,890 for each day remaining in the term
of the contract, subject to offset if the rig is otherwise employed. In
addition, either party can terminate the WAPET drilling contract after 20 days
of certain force majeure events and in the event of certain breaches.
In December 1997, the Company signed a contract with Jurong to upgrade
the MARINE 500 to fourth-generation capabilities for approximately $38 million.
Change orders have now increased the shipyard costs to approximately $48
million. In addition to this $48 million, the Company currently estimates that
the OFE will cost approximately $72 million, including capitalized interest and
project management costs, resulting in a total estimated cost to complete the
drilling rig of $120 million. Through December 31, 1998, the Company has paid
Jurong approximately $8 million in progress payments and paid approximately $49
million for OFE and other related construction costs. The contract anticipated
that the rig would arrive in the Singapore shipyard on July 15, 1998 and be
completed by December 31, 1998. Since the MARINE 500 did not arrive in the
shipyard until October 13, 1998 due to an extension of work under its previous
drilling contract, the Company now expects to complete construction of the
MARINE 500 during the second quarter of 1999. See "Construction and Contract
Risks" for discussion of risks associated with the MARINE 500 contracts.
MARINE 510 Charter. In July 1997, the Company entered into a Charter
Agreement with Shanghai Bureau of Marine Geological Survey ("SBMGS") to charter
the KANTAN 3 (now referred to as the MARINE 510), a semi-submersible rig, for a
period of five years. The MARINE 510 is a 600-foot water depth rig based upon
the Pacesetter design and was built in China in 1984. The Charter Agreement
began in mid-May 1998. The Charter Agreement and related agreements require the
Company to pay approximately $26,000 per day during the first year, $23,000 per
day during the second year and $24,500 per day for the last three years of the
charter for each day that the MARINE 510 is working. The MARINE 510 is currently
idle in Singapore. In January 1999, the Company reached a letter agreement with
SBMGS, subject to a definitive agreement, to amend the Charter. This amendment
will allow for a variable charter hire fee equal to 60% of rig operating profit
(dayrate revenue less operating expenses) and provides an option for the Company
to extend the Charter for up to five years beyond the original five year term.
Marketing Agreement for NANHAI VI. In August 1998, the Company entered
into an agreement effective through October 1, 1999, with China's Southern
Drilling Company to market the 1500-foot water depth rated semi-submersible
NANHAI VI. The NANHAI VI is a self-propelled, semi-submersible drilling rig,
which was built in 1982 and modified and refurbished in 1995. The rig is
technically and economically suitable to be upgraded to 4,000-foot water depth
capability. Estimated total lead time required to secure the equipment needed
for the upgrade, complete the project and move the rig to first drilling
location is one year. If the rig is required to be upgraded, the cost of the
upgrade will be funded by the owner. Under the agreement, the Company is to
receive $3,000 per day in management fees while the rig is operating and 50% of
all rig-level profits after management fees and amortization over a 36-month
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period of the costs of any upgrades to the vessel. The Company is actively
marketing the rig, which is currently working, but would be made available by
Southern Drilling Company upon consummation of a mutually agreeable drilling
contract.
CUSTOMERS
The Company provides drilling services to a customer base that includes
independent and major foreign and domestic oil and gas companies. As is typical
in the industry, the Company does business with a relatively small number of
customers at any given time. For the year ended December 31, 1998, the Company
performed services for approximately 25 different customers, of which Applied
Drilling Technology, Inc. accounted for approximately 24% of the Company's total
consolidated revenues and Carigali-Pttepi Operating Company Sdn Bhd, the
customer for the MARINE 500 prior to it going into the shipyard, accounted for
approximately 10% of revenues. During 1999, when the MARINE 700 and the MARINE
500 contracts begin, the Company expects that Esso and WAPET will account for
significant percentages of its revenues. See "Construction and Contracts Risks"
for discussion of risks associated with the MARINE 700 and MARINE 500 contracts.
The loss of any one of the Company's customers could, at least on a short-term
basis, have a material adverse effect on its profitability. See note 11 of the
audited consolidated financial statements for further information regarding the
Company's major customers.
ENVIRONMENTAL MATTERS
General. The Company is subject to numerous domestic and foreign
governmental laws and regulations that relate directly or indirectly to its
operations, including certain laws and regulations (a) controlling the discharge
of materials into the environment, (b) requiring removal and cleanup under
certain circumstances, (c) requiring the proper handling and disposal of waste
materials, or (d) otherwise relating to the protection of the environment. For
example, the Company, as an operator of mobile offshore drilling rigs in waters
of the United States and certain foreign offshore areas, may be liable for
damages and for the cost of removing oil spills for which it is held
responsible, subject to certain limitations. Laws and regulations protecting the
environment have become more stringent in recent years and may, in certain
circumstances, assess administrative, civil and criminal penalties and impose
"strict liability," rendering 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 and regulations at the time such acts were performed. The
application of these requirements or the adoption of new requirements could have
a material adverse effect on the Company. The Company believes that it has
conducted its operations in substantial compliance with all applicable
environmental laws and regulations.
The Company has generally been able to obtain contractual
indemnification in its drilling contracts against pollution and environmental
damages that are not caused by the gross negligence or willful misconduct of the
Company, but there can be no assurance that such indemnification will be
enforceable in all instances, that the customer will be financially able in all
cases to comply with its indemnity obligations, or that the Company will be able
to obtain such indemnification agreements in the future.
The Company maintains insurance coverage against certain environmental
liabilities, but there can be no assurance that such insurance will continue to
be available or carried by the Company or, if available and carried, will be
adequate to cover the Company's liability in the event of a catastrophic
occurrence.
U.S. Oil Pollution Act of 1990. The U.S. Oil Pollution Act of 1990
("OPA '90") and regulations promulgated pursuant thereto impose a variety of
regulations on "responsible parties" related to the prevention of oil spills and
liability for damages resulting from such spills. A "responsible party" includes
the owner or operator of an onshore facility, a pipeline or a vessel, or the
lessee or permittee of the area in which an offshore facility is located. OPA
'90 assigns liability to each responsible party for oil removal costs and a
variety of public and private damages. While liability limits apply in some
circumstances, a responsible party for an Outer Continental Shelf facility must
pay all spill removal costs incurred by a federal, state or local government.
OPA '90 establishes liability limits (subject to indexing) for mobile offshore
drilling rigs. If functioning as an offshore facility, the mobile offshore
drilling rigs are considered "tank vessels" for spills of oil on or above the
water surface, with liability limits of the greater of $1,200 per gross ton or
$10 million. To the extent damages and removal costs exceed this amount, the
mobile offshore drilling rigs will be treated as an offshore facility and the
offshore lessee will be responsible up to higher liability limits of all removal
costs
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plus $75 million. A party cannot take advantage of liability limits if the spill
was caused by gross negligence or willful misconduct or resulted from violation
of a federal safety, construction, or operating regulation. If the party fails
to report a spill or to cooperate fully in the cleanup, liability limits
likewise do not apply. Few defenses exist to the liability imposed by OPA '90.
OPA '90 also imposes ongoing requirements on a responsible party. A
failure to comply with ongoing requirements or inadequate cooperation in a spill
event may subject a responsible party to civil or criminal enforcement action.
In short, OPA '90 places a burden on drilling rig owners or operators to conduct
safe operations and take other measures to prevent oil spills. If a spill
occurs, OPA '90 then imposes liability for resulting damages.
The ongoing requirements of OPA '90 include proof of financial
responsibility (to cover at least some costs in a potential spill), and
preparation of an oil spill contingency plan. OPA requires owners and operators
of vessels over 300 gross tons to provide the U.S. Coast Guard with evidence of
financial responsibility to cover the costs of cleaning up oil spills from such
vessels. Moreover, certain amendments to OPA '90, that were enacted in 1996,
requires owners and operators of offshore facilities that have a worst case oil
spill potential of more than 1,000 barrels to demonstrate financial
responsibility in amounts ranging from $10 million in specified state waters to
$35 million in federal OCS waters, with higher amounts, up to $150 million, in
certain limited circumstances where the Minerals Management Service ("MMS")
believes such a level is justified by the risks posed by the quantity or quality
of oil that is handled by the facility. On August 11, 1998, the MMS promulgated
a final rule implementing the OPA '90 financial responsibility requirements for
offshore facilities. The MMS final rule applies to those facilities used for
exploring for, drilling for, or producing oil (including wells drilled from
mobile offshore drilling rigs) as well as facilities (e.g., pipelines) used to
transport oil from such exploration, drilling or production facilities. Vessels,
including mobile offshore drilling rigs functioning as vessels rather than
drilling platforms, are not subject to the MMS final rule but rather remain
subject to regulations administered by the U.S. Coast Guard. The Company
believes that it currently has established adequate proof of financial
responsibility for its mobile offshore drilling rigs functioning as offshore
facilities. However, the Company cannot predict whether financial responsibility
requirements under any subsequent amendments to OPA '90, if any, will result in
the imposition of substantial additional annual costs to the Company in the
future or otherwise materially adversely affect the Company. The impact of any
such future financial responsibility requirement should be no more burdensome on
the Company than on similarly situated or less capitalized drilling contractors
operating in U.S. waters.
Outer Continental Shelf Lands Act (U.S.). The Outer Continental Shelf
Lands Act authorizes regulations relating to safety and environmental protection
applicable to lessees and permittees operating on the Outer Continental Shelf.
Specific design and operational standards may apply to Outer Continental Shelf
vessels, rigs, platforms, vehicles and structures. Violations of lease terms
relating to environmental matters or regulations issued pursuant to the Outer
Continental Shelf Lands Act can result in substantial civil and criminal
penalties as well as potential court injunctions curtailing operations and the
cancellation of leases. Such enforcement liabilities can result from either
governmental or citizen prosecution.
CERCLA and RCRA (U.S.). The Comprehensive Environmental Response,
Compensation, and Liability Act of 1980 ("CERCLA"), as amended, currently
exempts crude oil, and the Resource Conservation and Recovery Act ("RCRA"), as
amended, currently exempts certain drilling materials, such as drilling fluids
and produced water, from the definitions of hazardous substances and hazardous
wastes for purposes of these statutes. The Company's operations, however, may
involve the use or handling of other material that may be classified as
environmentally hazardous substances or wastes. There can be no assurances that
these exemptions will be preserved in future amendments of such acts, if any, or
that more stringent federal or state laws and regulations protecting the
environment will not be adopted. CERCLA assigns strict liability to each
responsible party for all response and re-mediation costs, as well as natural
resource damage. Few defenses exist to the liability imposed by CERCLA.
GOVERNMENTAL REGULATION
The Company's business is affected by political developments and by
federal, state, foreign and local laws and regulations that relate directly to
the oil and gas industry. The adoption of laws and regulations curtailing
exploration and developmental drilling for oil and gas for economic,
environmental or other policy reasons would and have adversely affected the
operations of the Company by limiting available drilling opportunities for its
customers and/or
7
<PAGE> 10
increasing the costs of such activities to the Company or its customers. The
Company believes that it has conducted its operations in substantial compliance
with applicable governmental laws and regulations.
OPERATIONAL RISKS AND INSURANCE
Contract drilling operations are subject to various risks including
blowouts, cratering, fires and explosions, each of which could result in damage
to or destruction of drilling rigs and oil and gas wells, damage to life and
property, suspension of operations, and environmental damage through oil
spillage and extensive uncontrolled fires. The Company insures its drilling rigs
and plant assets for amounts approximating used equipment replacement cost and
also insures against catastrophic losses resulting from employer's liability and
other risks customary in the energy service industry. The Company currently
maintains insurance coverage it believes to be customary in the industry against
certain general and marine public liabilities, including liabilities for
personal injuries. Except in limited circumstances, this insurance does not
cover liability for pollution or environmental damage that originates below the
water surface, although the Company is generally indemnified against such
pollution and environmental liabilities by its customers. There is no assurance
that such insurance or indemnification will be adequate to protect the Company
against liability from all consequences of well disasters, extensive fire damage
or damage to the environment. Recognizing these risks, the Company has programs
that are designed to promote a safe environment for its personnel and equipment.
COMPETITION
The contract drilling industry is highly competitive, and the Company
competes with many drilling contractors, which are substantially larger than the
Company with greater financial and other resources. Customers often award
contracts on a competitive bid bases, and although a customer selecting a rig
may consider, among other things, a contractor's safety record, crew quality and
quality of service and equipment, the historical oversupply of rigs has created
an intensely competitive market in which price is the primary factor in
determining the selection of a drilling contractor. The Company believes that
competition for drilling contracts will continue to be intense in the
foreseeable future. Contractors are also able to adjust localized supply and
demand imbalances by moving rigs from areas of low utilization and day rates to
areas of greater activity and relatively higher day rates. In addition, there
are inactive non-marketed rigs that could be reactivated to meet an increase in
demand for drilling rigs in any given market. Such movements or reactivations or
a decrease in drilling activity in any major market could depress day rates and
could adversely affect utilization of the Company's rigs.
In addition, the improvement the offshore contract drilling industry as
a whole experienced during 1997 led to increased rig construction and
enhancement programs by the Company and its competitors. A significant increase
in the supply of new or enhanced rigs may have an adverse effect on the average
operating day rates for the Company's rigs, particularly its semi-submersible
units, and on the overall utilization level of the Company's fleet. The
availability of other suitable rigs and the currently depressed market
conditions could cause customers to attempt to renegotiate their long-term
contracts with the Company or even attempt to cancel their contracts. In such
cases, the Company's results of operations would be adversely affected.
INTERNATIONAL OPERATIONS
The Company's international operations are also subject to certain
political, economic and other uncertainties including, among others, risks of
war and civil disturbances, expropriation, nationalization, renegotiation or
nullification of existing contracts, taxation policies, environmental
regulation, foreign exchange restrictions, changing political conditions,
international monetary fluctuations and other hazards arising out of foreign
governmental sovereignty over certain areas in which the Company conducts
operations. To date the Company has experienced no material loss as a result of
any of these factors.
CONSTRUCTION AND CONTRACT RISKS
The Company is currently undertaking significant capital expenditures
in connection with constructing the MARINE 700 and upgrading the MARINE 500, and
may undertake significant capital projects on other rigs in the future. As in
any other large construction project, these projects may be delayed or have cost
overruns because of material and skilled labor shortages, engineering problems,
damage to current equipment, work stoppages, weather, costs increases and
problems in the permitting and approval process. Significant cost overruns or
delays would affect the Company's revenue and profitability. The Company is
dependent on the shipyards performing the work on both the
8
<PAGE> 11
MARINE 700 and MARINE 500. See "Contracts" for a description of delay and cost
overruns the Company has encountered on the MARINE 700 and MARINE 500 projects.
MARINE 700 Construction and Contract Risks. The Company is currently
constructing the MARINE 700 in order to provide service to Esso under a
five-year contract with a base dayrate of $165,410 per day. If the Company fails
to perform under this contract, it could be forced to re-negotiate significant
terms of the contract such as dayrate and term or be forced to find an alternate
customer for the rig. Due to current market conditions, the Company would likely
not be able to negotiate as favorable contract terms as those of the existing
contract, and/or there may be delays in finding an alternate customer, which
would adversely affect future revenues.
The specific design for the MARINE 700 has not been used before
although it is a variation of a design used in a number of currently operating
rigs. In addition, the MARINE 700 is the first new-build project for the
Pascagoula, Mississippi shipyard building it although the shipyard's parent
company has significant experience and has allocated experienced supervisors to
the project.
The MARINE 700 contract requires that the rig meet certain design
specifications and construction quality standards. If the unit does not meet
these specifications and standards then Esso may terminate the contract. In
order to ensure the specifications and standards are met, the shipyard and the
Company have quality assurance and quality control programs in place. These
programs are reviewed periodically by the shipyard, Esso and the Company to
ensure adequate quality standards and compliance. When quality deficiencies are
identified, action is taken to rectify the deficiency and procedures are
modified to ensure future compliance with the quality standard. Esso, the
shipyard and the Company all participate in the quality assurance and control
program and openly share information gained through the process. Construction
quality standards are further supported by the classing agency's testing of
design and construction quality.
In addition to the design specifications being met, the rig must be
delivered by July 15, 1999. If the Company does not deliver the rig by July 15,
1999 or fails to meet the contractual design specifications, then Esso may
cancel the contract unless the delay is caused by Esso or its' subcontractors.
Due to construction, engineering, weather and other delays, the current
scheduled delivery date for the MARINE 700 has been delayed from February 1999
to late in the second quarter of 1999. In an effort to minimize any further
delays and to address concerns regarding the project raised by the Company and
Esso, the shipyard and the Company substantially increased the personnel
working on the project which has significantly increased the project's
completion pace. The costs of the increased personnel are included in the
Company's current budgets for the project discussed in "Management's Discussion
and Analysis of Financial Condition and Results of Operations-Financial
Condition-Liquidity and Capital Resources." In addition, the shipyard, working
together with the Company and Esso, has enhanced, and attempted to tailor to
Esso's preferences, the quality assurance and quality control programs
applicable to the project. While there is some probability that the Company
will not deliver the rig by late second quarter due to the risks commonly
associated with large construction projects. The Company believes that the unit
will be delivered late in the second quarter of 1999; however, there is a risk
that the Company will not meet the delivery deadline of July 15, 1999 due to the
complexity inherent in these type of large construction projects.
MARINE 500 Contract and Upgrade Risks. In July 1997, the Company
entered into a three-year drilling contract for the MARINE 500 with a drilling
consortium led by West Australian Petroleum Pty, Ltd. ("WAPET"). The contract
requires that the Company, prior to delivery of the rig, upgrade the MARINE 500
to meet certain performance specifications including being capable of working in
up to 5,000 feet of water. The contract was originally scheduled to commence
during January 1999; however, due to an extension of work under the prior
drilling contract, the rig was delayed in arriving at the shipyard for upgrade
work thus the Company does not expect the MARINE 500 to be available to WAPET
until the second quarter of 1999. Delivery delays, or any material failure to
meet design specifications pursuant to the WAPET contract, could jeopardize the
WAPET contract.
EMPLOYEES
As of March 10, 1999, the Company had approximately 895 employees. The
number of employees varies throughout the year depending on the level of
drilling activity. The Company considers relations with its employees to be
good. None of the Company's employees is presently represented by labor unions.
9
<PAGE> 12
Crew quality is an important factor considered by the customer in
selecting a rig. Accordingly, the Company seeks experienced personnel when
selecting crews from among the available applicants and the Company maintains a
safety and personnel training program.
ITEM 2. PROPERTIES
DRILLING RIG FLEET
Jack-up Rigs. The Company owns 15 jack-up rigs. Jack-up rigs are mobile
self-elevating drilling platforms equipped with legs that can be lowered to the
ocean floor until a foundation is established to support the drilling platform.
An offshore jack-up rig consists of a hull, which supports the drilling
equipment, jacking system, crew quarters, loading and unloading facilities,
storage areas for bulk and liquid materials, helicopter landing deck and other
related equipment. The rig legs may operate independently or have a lower hull
or mat attached to the lower portion of the legs in order to provide a more
stable foundation in soft bottom areas.
Nine of the Company's rigs are mat supported rigs and six are of
independent leg design. Five of the mat supported rigs and one of the
independent leg rigs are of slot type design, which are configured for the
drilling operations to take place through a slot in the hull. The Company's
other four mat supported rigs and three of the independent leg rigs have a
cantilever feature which allows the extension of the drilling equipment over a
customer's platform to perform development drilling or workover operations. The
Company's jack-up rigs are capable of drilling to depths of 20,000 to 30,000
feet in maximum water depths ranging from 200 to 300 feet.
There are several factors that determine the type of rig most suitable
for a particular job, the most significant of which include the water depth and
bottom conditions at the proposed drilling location, whether the drilling is
being done over a platform or other structure, and the intended well depth.
Independent leg jack-up rigs typically have greater water depth capability and
are advantageous in offshore areas where uneven bottom conditions or
obstructions, such as pipelines, exist. Mat supported rigs are advantageous in
offshore areas with soft bottom conditions. A slot design is appropriate for
drilling exploratory wells in the absence of any existing permanent structure,
such as a production platform, although some slot design rigs are capable of
drilling over production platforms. A cantilevered jack-up can extend its drill
floor and derrick over an existing, fixed structure, thereby permitting the rig
to drill or work over a well located on such a structure. Jack-up rigs with the
cantilever feature historically have achieved higher utilization and dayrates.
The Company has top drive drilling systems installed on ten of its
rigs. A top drive drilling system allows drilling with 90-foot lengths of drill
pipe rather than 30-foot lengths, thus reducing the number of required
connections. A top drive drilling system also permits rotation of the drill
string while tripping in or out of the hole. These characteristics increase
drilling speed, personnel safety and drilling efficiency and reduce the risk of
the drill string sticking during operations.
Currently the Company has two jack-up rigs located in international
markets. The Company has three additional rigs located in the U.S. Gulf of
Mexico which are suitable for operations in selected international waters and
its other rigs could, with certain modifications, work in other international
markets. The Company's jack-ups, except for the MARINE 306, are not suitable for
those areas that require hostile environment capabilities, such as the North
Sea, or in deep waters in excess of 200 to 300 feet.
Semi-submersible Rigs. The Company owns two semi-submersibles, the
MARINE 700 and the MARINE 500, and has a long-term charter on one additional
semi-submersible, the MARINE 510. The MARINE 700 is presently under construction
and the MARINE 500 is presently being upgraded. Semi-submersibles operate in
various market areas around the world usually in water depths where jack-up rigs
are incapable of working. Semi-submersible rigs consist of an upper working and
living deck resting on vertical columns connected to lower hull members. Such
rigs operate in a "semi-submerged" position, remaining afloat, off bottom, in a
position in which the lower hull is from about 55 to 90 feet below the water
line and the upper deck protrudes well above the surface. The rig is typically
anchored in position and remains stable for drilling in the semi-submerged
floating position due in part to its wave transparency characteristics at the
water line. Semi-submersible rigs normally require water depth of at least 200
10
<PAGE> 13
feet in order to conduct operations. Typically semi-submersible rigs are more
expensive to construct and operate than jack-up rigs.
The following table describes the Company's drilling rigs as of
March 10, 1999:
<TABLE>
<CAPTION>
YEAR
BUILT/ RATED WATER RATED DRILLING
NAME OF RIG MAKE/DESIGN TYPE UPGRADED DEPTH DEPTH LOCATION
----------- ----------- ---- -------- ----- ----- --------
<S> <C> <C> <C> <C> <C> <C>
Independent Leg Jack-up Rigs:
MARINE 300 T(a)(b)(c) F&G*/L780 MOD II Cantilever 1981 250' 30,000' U.S. Gulf of Mexico
MARINE 301 T F&G*/L780 MOD II Cantilever 1981 300' 25,000' U.S. Gulf of Mexico
MARINE 303 T(c) F&G*/L780 MOD II Cantilever 1982 300' 30,000' U.S. Gulf of Mexico
MARINE 304 T(c) MLT**/84S Slot 1976/1993 300' 30,000' U.S. Gulf of Mexico
MARINE 305 T(c) Levingston III-S Cantilever 1975/1997 300' 30,000' Southeast Asia
MARINE 306 Gusto Engineering Accommodation 1975/1997 205' N/A North Sea
Unit
Mat Supported Jack-up Rigs:
MARINE 3 Bethlehem/262 Slot 1974 262' 25,000' U.S. Gulf of Mexico
MARINE 4 Bethlehem/250 Slot 1975 250' 25,000' U.S. Gulf of Mexico
MARINE 15 T Baker Marine/250 Slot 1981/1996 250' 25,000' U.S. Gulf of Mexico
MARINE 16 T Bethlehem/250 Slot 1981/1995 250' 20,000' U.S. Gulf of Mexico
MARINE 17 Bethlehem/200 Cantilever 1981 200' 20,000' U.S. Gulf of Mexico
MARINE 18 Bethlehem/250 Cantilever 1982 250' 20,000' U.S. Gulf of Mexico
MARINE 200 T Bethlehem/200 Cantilever 1981 200' 20,000' U.S. Gulf of Mexico
MARINE 201 T(c) Bethlehem/200 Cantilever 1981/1995 200' 20,000' Middle East
MARINE 225 Bethlehem/225 Slot 1969/1993 225' 20,000' U.S. Gulf of Mexico
Semi-Submersible Rigs:
MARINE 500 T(c)(d) Offshore Co. Semi-Submersible 1975/1999 5000' 30,000' Southeast Asia
MARINE 700(c)(e) Bingo 8000 Semi-Submersible 1999 5000' 30,000' U.S. Gulf of Mexico
MARINE 510(c)(f) 6 Col Dual Pontoon Semi-Submersible 1984/1996 600' 20,000' Southeast Asia
</TABLE>
- ---------------------
(a) Can be modified to provide for 300-foot water depth capability.
(b) Designed to operate in environmentally sensitive areas such as Mobile Bay.
(c) Configured for international operations.
(d) Currently undergoing significant upgrades expected to be completed in the
second quarter of 1999, which will increase its rated water depth from 600
feet to 5,000 feet.
(e) Currently under construction and is expected to be complete late in the
second quarter of 1999.
(f) Operated under a five-year charter agreement that expires in April 2003.
See "Business - Contracts -- MARINE 510 Charter."
T Equipped with top drive drilling system.
* Friede & Goldman.
** Marathon LeTourneau.
In addition to the drilling rigs described above, in August 1998 the
Company entered into an agreement with the owner of the NANHAI VI, a 1500-foot
water depth semi-submersible, to market that rig on an exclusive basis. See
"Business - Contracts -- Marketing Agreement for NANHAI VI."
11
<PAGE> 14
[PICTURE OF INDEPENDENT LEG JACK-UP RIG]
Independent Leg Jack-up Rig - This type of rig consists of a floating
hull with three independent elevated legs. After being towed to the drilling
location, the legs are lowered until they penetrate the seabed and the hull is
jacked to the desired elevation above sea level. The rig depicted in the diagram
has a cantilever feature that permits the rig to operate over an existing, fixed
platform or other structure.
[PICTURE OF MAT SUPPORTED JACK-UP RIG]
Mat Supported Jack-up Rig - This type of rig consists of a floating
upper hull with three legs which are attached to a lower hull commonly referred
to as a mat. After being towed to the drilling location, the legs are lowered
until the mat contacts the seabed and the upper hull is jacked to the desired
elevation above sea level. One advantage of mat supported rigs is the ability to
operate in areas having soft seabed conditions where independent leg rigs are
prone to have excessive penetration and subject to leg damage. The rig depicted
is cantilevered.
[PICTURE OF SEMI-SUBMERSIBLE RIG]
Semi-submersible Rig - This type of rig consists of an upper working
and living deck resting on vertical columns connected to lower hull members.
Such rigs operate in a "semi-submerged" position, remaining afloat, off bottom,
in a position in which the lower hull is from about 55 to 90 feet below the
water line and the upper deck protrudes well above the surface. The rig is
typically anchored in position and remains stable for drilling in the
semi-submerged floating position due in part to its wave transparency
characteristics at the water line.
12
<PAGE> 15
FACILITIES
The Company's principal executive offices are located in Sugar Land,
Texas, a suburb of Houston, and consists of approximately 19,000 square feet of
leased space. The Company also leases a warehouse, storage and repair facility,
including approximately 31 acres of land and 60,000 square feet of buildings, in
Rosharon, Texas (near Houston). In connection with the Company's foreign
operations the Company leases offices, warehouse space and/or employee living
quarters in Australia, Indonesia and Singapore.
ITEM 3. LEGAL PROCEEDINGS
LITIGATION
Jagson International Limited ("Jagson"), an Indian entity, has brought
suit against Marine Drilling Companies, Inc. and Marine 300 Series, Inc. The
plaintiff has alleged that the Company agreed to charter two jack-up rigs to the
plaintiff during 1992 and that the Company breached the agreement by failing to
charter the rigs resulting in damages in excess of $14,500,000. In August 1995,
Jagson filed a suit against the Company in New Delhi, India that was
subsequently withdrawn and filed a second suit in New Delhi against the Company
in October 1995 that was dismissed by the court. In May 1996, Jagson filed a
third suit against the Company in Bombay, India for the same claim and attempted
to attach the MARINE 201, located in India at the time, to the claim. In March
1998, the court dismissed the motion for attachment. Although the third suit is
still on file with the court, the MARINE 201 is no longer in India and there
have been no further proceedings in the lawsuit. The Company disputes the
existence of the agreement and intends to vigorously defend the suit. The
Company does not believe this dispute will have a material adverse effect on its
results of operations or financial condition.
Various other claims have been filed against the Company and its
subsidiaries in the ordinary course of business, particularly claims alleging
personal injuries. Management believes that the Company has adequate insurance
coverage and has established adequate reserves for any liabilities that may
reasonably be expected to result from these claims. In the opinion of
management, no pending claims, actions or proceedings against the Company or its
subsidiaries are expected to have a material adverse effect on its financial
position or results of operations.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
There were no matters submitted to a vote of security holders during
the fourth quarter of the fiscal year covered by this report.
13
<PAGE> 16
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON STOCK AND RELATED SHAREHOLDER MATTERS
The Company's common stock, par value $.01 per share (the "Common
Stock") trades on the New York Stock Exchange ("NYSE") under the symbol "MRL."
Until August 14, 1998, the Common Stock was traded on the NASDAQ National Market
System. The following table sets forth the range of high and low sale prices per
share of the Common Stock as reported by the NYSE and the NASDAQ National Market
System for the periods indicated.
<TABLE>
<CAPTION>
1999 HIGH LOW
----------- -----------
<S> <C> <C>
First Quarter (through March 10, 1999)...................... $ 9 9/16 $ 5 15/16
1998
First Quarter .............................................. $ 24 1/8 $ 13 1/8
Second Quarter.............................................. 26 11/16 14 3/4
Third Quarter............................................... 16 5/16 8
Fourth Quarter.............................................. 12 3/4 7
1997
First Quarter............................................... $ 24 $ 12 7/8
Second Quarter.............................................. 21 1/4 13 3/4
Third Quarter............................................... 31 13/16 19 3/4
Fourth Quarter.............................................. 36 1/16 17
1996
First Quarter............................................... $ 8 3/4 $ 4 7/8
Second Quarter.............................................. 10 11/16 7 7/8
Third Quarter............................................... 10 7/8 8 3/8
Fourth Quarter.............................................. 20 3/4 9 1/8
</TABLE>
The last sale price of the common stock as reported by the NYSE on
March 8, 1999 was 8 9/16 per share and there were approximately 701 holders of
record.
The Company has not paid cash dividends on its common stock in the past
and does not intend to pay dividends on the common stock in the foreseeable
future. The Company's credit facility limits the ability of the Company to pay
dividends. See Item 7 "Management's Discussion and Analysis of Financial
Condition and Results of Operations" and the Consolidated Financial Statements
and Notes thereto included in Item 8 of this report.
14
<PAGE> 17
ITEM 6. SELECTED CONSOLIDATED FINANCIAL DATA
The following table sets forth selected consolidated financial data of
the Company as of and for each of the periods indicated. The selected financial
data as of and for the five year period ended December 31, 1998 are derived from
the Company's audited consolidated financial statements. The information
presented below should be read in conjunction with Item 7 "Management's
Discussion and Analysis of Financial Condition and Results of Operations" and
the Consolidated Financial Statements and Notes thereto included in Item 8 of
this report.
<TABLE>
<CAPTION>
AS OF OR FOR THE YEAR ENDED DECEMBER 31,
------------------------------------------------------------------
1998 1997 1996 1995 1994
--------- --------- --------- --------- ---------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<S> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA:
Drilling revenues $ 228,015 $ 190,257 $ 110,329 $ 63,067 $ 70,597
Drilling expenses 102,166 77,847 59,770 55,091 50,575
Depreciation and amortization 20,191 16,995 11,576 9,377 7,733
General and administrative 12,287 7,807 7,498 5,460 4,376
Operating income (loss) 93,371 87,608 31,485 (6,861) 7,913
Interest income, net 1,202 1,823 366 639 1,280
Income (loss) before income taxes 95,541 89,836 32,256 (6,102) 9,123
Income tax expense (benefit) 34,720 31,456 11,586 (2,080) 3,193
Net income (loss) $ 60,821 $ 58,380 $ 20,670 $ (4,022) $ 5,930
Basic average common shares outstanding 52,217 51,572 44,918 43,812 43,819
Diluted average common shares outstanding 52,726 52,452 45,748 43,812 44,802
EARNINGS PER SHARE DATA:
Basic $ 1.16 $ 1.13 $ 0.46 $ (0.09) $ 0.14
Diluted $ 1.15 $ 1.11 $ 0.45 $ (0.09) $ 0.13
BALANCE SHEET DATA:
Cash and cash equivalents $ 12,576 $ 20,619 $ 71,961 $ 12,260 $ 18,872
Short-term investments -- -- 9,990 -- 18,137
Working capital 6,699 55,472 96,671 23,316 48,529
Total assets 475,684 334,182 254,947 134,545 143,215
Long-term debt, non-current 50,000 -- 9,000 9,000 15,000
Deferred income taxes 29,128 18,090 13,729 6,144 8,365
Shareholders' equity 361,588 295,742 221,733 107,572 112,731
</TABLE>
15
<PAGE> 18
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
INDUSTRY OVERVIEW
Demand for the Company's offshore drilling services is primarily driven
by the worldwide expenditures for oil and gas drilling which is closely linked
to the underlying economics of oil and gas exploration, development and
production. The economics of oil and gas business activities is impacted by
current and projected oil and gas prices. Since the early 1980's, oil and gas
prices have been volatile and somewhat unpredictable, which has caused
significant fluctuations in oil and gas drilling expenditures. Many factors
influence oil and gas prices, including world economic conditions, worldwide oil
and gas production and the activities of the Organization of Petroleum Exporting
Countries ("OPEC").
The rates that the industry can charge for drilling services is a
function of not only demand for services but the supply of drilling rigs
available in the market to provide service. During the early 1980's when oil and
gas prices were high and significant demand for drilling services existed, the
industry built a significant number of offshore drilling rigs. In the mid-1980's
when oil and gas prices declined significantly and the corresponding demand for
drilling services declined, the supply of drilling rigs was significantly
greater than the industry needed. This resulted in an imbalance of supply and
demand causing low utilization with dayrates declining to virtually cash
operating costs.
During 1996 and early 1997, oil and gas prices rose to a level that
stimulated significant oil and gas drilling activity resulting in improved
utilization and dayrates for the drilling industry. However, oil and gas prices
have declined significantly since October 1997, and have reached multi-year lows
in various markets in recent months. As a result, oil and gas companies have
made significant cutbacks in their drilling programs. This has reduced
industry-wide rig utilization including the U.S. Gulf of Mexico, where the
Company operates most of its rigs, which has not only sharply reduced dayrates,
but also shortened the average length of drilling contracts.
The following table sets forth current rig utilization rates and
average utilization rates for 1998, 1997 and 1996, according to Offshore Data
Services:
<TABLE>
<CAPTION>
AS OF
MARCH 9, 1999 1998 1997 1996
-------------------- -------------------- -------------------- --------------------
<S> <C> <C> <C> <C>
Gulf of Mexico jack-up rigs 59% 81% 90% 87%
Worldwide jack-up rigs 67% 83% 89% 86%
Worldwide semi-submersible rigs 63% 78% 81% 79%
</TABLE>
As of March 10, 1999, nine of the Company's 15 jack-up rigs are
committed under short-term contracts that will expire in the first or second
quarter of 1999, one rig is under contract for one year, and the remaining 5
rigs are idle. All of the currently committed rigs are in the U.S. Gulf of
Mexico. The Company currently has no international rigs working. In addition to
the recent declines in rig utilization, current dayrates for drilling rigs are
substantially less than the dayrates that generally prevailed during most of
1998. These current market conditions will adversely affect the Company's
results of operations for at least the near term, substantially reducing its
revenues, cash flows and earnings and likely resulting in losses in 1999 until
the MARINE 700 and the MARINE 500 begin operations. Oil and gas prices may
continue to deteriorate, and the Company cannot predict whether or when they
might recover.
RESULTS OF OPERATIONS
The number of rigs the Company has available for service and the
utilization rates and dayrates of the Company's active rigs are the most
significant factors affecting the Company's level of revenues. Operating costs
include all direct costs and expenditures associated with operating the
Company's rigs. These costs include rig labor, repair, maintenance and supply
expenditures, insurance costs, mobilization costs and other costs related to
operations. Operating expenses do not necessarily fluctuate in proportion to
changes in operating revenues due to the cost of maintaining personnel on board
the rigs and equipment maintenance when the rigs are idle. Labor costs increase
primarily due to higher salary levels, rig staffing requirements and inflation.
Equipment maintenance expenses fluctuate
16
<PAGE> 19
depending upon the type of activity the rig is performing and the age and
condition of the equipment. Inflation is another contributing factor in the
fluctuation of operating expenses.
The changes in operating income are more directly affected by revenue
factors than expense factors since changes in dayrates directly impact revenues
but not expenses. Utilization rate changes have a significant impact on
revenues, but in the short-term do not impact expenses. Over a long period
significant changes in utilization may cause the Company to adjust the level of
its actively marketed rig fleet and labor force to match anticipated levels of
demand, thus changing the level of operating expenses. General and
administrative expenses do not vary significantly unless the Company materially
expands its asset base. Depreciation, which is affected by the Company's level
of capital expenditures and depreciation practices is another major determinant
of operating income, and is not affected by changes in dayrates or utilization.
The following table sets forth the average rig utilization rates,
operating days, average day rates, revenues and operating expenses of the
Company by operating segments for the periods indicated (dollars in thousands
except per day data):
<TABLE>
<CAPTION>
FOR THE YEARS ENDED DECEMBER 31,
-----------------------------------------------------------
1998 1997 1996
------------ ----------- -------------
<S> <C> <C> <C>
Jack-ups:
Operating days 4,732 4,739 4,532
Utilization (1) 93% 100% 99%
Average revenue per day $ 40,719 $ 36,324 $ 24,343
Revenue 192,667 172,143 110,329
Contract drilling expense(2) 81,030 67,607 59,437
Depreciation 13,923 11,260 9,912
Operating income 97,714 93,276 40,980
Semi-submersibles: (3)
Operating days 460 294 -
Utilization (1) 90% 93% -
Average revenue per day $ 76,864 $ 61,714 $ -
Revenue 35,348 18,114 -
Contract drilling expense(2) 21,136 10,240 333
Depreciation 3,272 3,242 -
Operating income 10,940 4,632 (333)
Total Company:
Operating days 5,192 5,033 4,532
Utilization (1) 92% 99% 99%
Average revenue per day $ 43,917 $ 37,805 $ 24,343
Revenue 228,015 190,257 110,329
Contract drilling expense(2) 102,166 77,847 59,770
Depreciation 20,191 16,995 11,576
General and administrative expense 12,287 7,807 7,498
Operating income 93,371 87,608 31,485
</TABLE>
(1) Based on the number of actively marketed rigs. Excluding rigs under
construction or in the process of substantial upgrading, the Company had an
average of 0.1, 1.1, and 0.9 non-marketed rigs during 1998, 1997 and 1996,
respectively.
(2) Excludes depreciation and amortization and general and administrative
expenses.
(3) The Company did not operate any semi-submersibles prior to 1997.
17
<PAGE> 20
Years Ended December 31, 1998 and 1997
Revenues. The Company's 1998 drilling revenues increased $37,758,000 or
20%, compared to 1997. The increase in revenues was primarily due to a 16%
increase in average daily revenue to $43,917. An increase of 159 operating days
in 1998 also contributed to the increased revenues due to placing the MARINE 305
into service in August 1997 and the MARINE 510 in May 1998. Partially offsetting
these increases was a 7% decline in rig utilization to 92% in 1998 from 99% in
1997.
Costs and Expenses. Contract drilling expenses in 1998 increased
$24,319,000 or 31% compared to 1997. The increase was primarily a result of
increased fleet size in the international market. The MARINE 305 was placed into
service in August 1997 and the MARINE 510 in May 1998. International rig
operations typically have higher average operating costs than domestic rig
operations.
Depreciation and Amortization. Depreciation and amortization expense
for 1998 increased $3,196,000 (19%) from $16,995,000 to $20,191,000 compared to
the same period in 1997. The increase in 1998 was due to a full year of
depreciation in 1998 associated with 1997 expenditures for the acquisition of
the MARINE 500 and upgrade of the MARINE 305.
General and Administrative. General and administrative expenses
increased $4,480,000 or 57% to $12,287,000 in 1998 from $7,807,000 in 1997. The
increase was attributed to an increase in professional services and increased
personnel costs consistent with the increased level of operations, new deepwater
contracts and increased international activity.
Interest Expense. Interest expense for 1998 was $481,000 compared to
$575,000 during 1997. The decrease was primarily the result of the prepayment
and termination of the Company's $35 million credit facility in February 1997.
Interest Income. Interest income decreased $715,000 or 30% from
$2,398,000 in 1997 to $1,683,000 in 1998. The decrease was related primarily to
decreased cash balances throughout the year as a result of expenditures related
to the Company's two major construction and upgrade projects.
Income Taxes. Income tax expense increased for 1998 as compared to the
same period in 1997, primarily due to an increase in the Company's pretax
income.
Years Ended December 31, 1997 and 1996
Revenues. The Company's 1997 drilling revenues increased $79,928,000 or
72%, compared to 1996. Revenue increases from jack-up drilling operations
accounted for $61,814,000 of the increase. This increase was mainly attributable
to increased day rates and slightly better utilization in 1997 compared to 1996
and the activation of the Marine 305 during August 1997 in Southeast Asia that
contributed $9,413,000 to the increase. The remaining $18,114,000 increase in
revenues was from placing the Marine 500, the Company's first semi-submersible,
into service the beginning of 1997.
Costs and Expenses. Contract drilling expenses in 1997 increased
$18,077,000 or 30% compared to contract drilling expenses in 1996. Of the
$18,077,000 increase, $8,170,000 can be attributed to jack-up drilling
operations. The addition of the Marine 305 was responsible for $4,052,000 of the
increase. Labor costs due to higher salaries and additional personnel along with
increased maintenance costs partially offset by decreases in employer's
liability claims accounted for the remaining $4,118,000 attributed to jack-up
operations. The remaining increase in operating costs of $9,907,000 is due to
the operation of the Company's semi-submersible rig the Marine 500 which began
operating during the first quarter of 1997.
Depreciation and Amortization. Depreciation and amortization expense
for 1997 increased $5,419,000 (47%) from $11,576,000 to $16,995,000 compared to
the same period in 1996. The increase was due to depreciation associated with
expenditures for the following items: (i) the acquisition of the MARINE 500,
(ii) acquisition of the MARINE 305,
18
<PAGE> 21
(iii) upgrades to the MARINE 15 and the MARINE 300; and (iv) acquisitions of
drill string and other drilling equipment.
General and Administrative. General and administrative expenses in 1997
increased $309,000 or 4% from $7,498,000 in 1996 to $7,807,000. The increase was
attributed to an increase in professional services and other administrative
expenses.
Interest Expense. Interest expense in 1997 was $575,000. The Company
had interest expense of $895,000 during 1996. The decrease was primarily the
result of the prepayment and termination of the Company's $35 million credit
facility in February 1997.
Interest Income. Interest income increased $1,137,000 or 90% from
$1,261,000 in 1996 to $2,398,000 in 1997. The increase was related primarily to
increased cash balances throughout the year, and to a lesser extent, higher
interest rates.
Income Taxes. Income tax expense increased for 1997 as compared to the
same period in 1996, primarily due to an increase in the Company's pretax
income.
FINANCIAL CONDITION -- LIQUIDITY AND CAPITAL RESOURCES
Liquidity. At December 31, 1998, the Company had working capital of
$6,699,000 as compared to working capital of $55,472,000 at December 31, 1997.
Net cash provided by operating activities for the year ended December 31, 1998
increased by $60,523,000 to $133,108,000 compared to $72,585,000 for the same
period in the prior year. The increase is primarily attributable to the
increased dayrates and rig operating activity coupled with the timing of cash
receipts and payments. Cash used in investing activities increased $76,575,000
in 1998 to $191,892,000 from $115,317,000 in 1997 due to $190,896,000 of capital
expenditures, which were primarily related to the construction of the MARINE 700
and the MARINE 500 upgrade. Net cash provided by financing activities during
1998 was $50,741,000 consisting primarily of $50,000,000 in proceeds from
long-term debt borrowings.
In March 1997, the Company entered into a credit agreement ("Credit
Facility") with certain banks providing financing up to $100 million to be used
for rig acquisitions and upgrades. This agreement included a revolving credit
facility available through December 31, 1999 at which point, it converted into a
four-year term loan. The Credit Facility called for interest and facility fees
to be paid quarterly during the terms of both facilities. The term loan facility
provided for equal quarterly principal payments beginning March 31, 2000.
Interest accrues at a rate of (i) LIBOR plus a margin of .75% to 1.25% or (ii)
prime plus a margin of 0% to .50%, with margins determined pursuant to a debt to
capital calculation. The borrowings were secured by all of the Company's rig
fleet, except for the MARINE 700, as well as certain other assets. In connection
with the consummation of the Credit Facility, the Company repaid and terminated
its former $35 million credit facility with a U.S. financial institution.
On August 12, 1998, the Company entered into an agreement (the "Amended
Credit Facility") with a consortium of domestic and international banks, which
amends the Credit Facility to a five-year revolver maturing August 2003,
eliminates the term loan conversion feature and increases the credit line to
$200 million. The Amended Credit Facility is now secured by substantially all of
the Company's assets, including its rig fleet. The Company and its subsidiaries
are required to satisfy customary lending conditions and comply with various
covenants and restrictions, including, but not limited to, the maintenance of
financial ratios and the restriction on payments of dividends. Interest accrues
at a rate of (i) LIBOR plus a margin of .75% to 1.25% with margins determined
pursuant to a debt to EBITDA calculation or (ii) prime if a Base Rate Loan. The
Company drew down $50 million on the facility during the fourth quarter of 1998.
If currently depressed market conditions continue, the Company expects
that it will incur losses and substantially reduced EBITDA in 1999 until the
MARINE 700 and the MARINE 500 begin operations. In addition, the Company has
been substantially increasing its indebtedness under the Amended Credit Facility
to fund construction costs on the MARINE 700 and the MARINE 500(approximately
$80 million was outstanding on March 10, 1999). As a result, unless there is a
significant near-term improvement in market conditions, the Company, later in
1999, will likely be unable to satisfy the ratio of indebtedness to EBITDA
financial covenant in the Amended Credit Facility. This covenant requires the
ratio of indebtedness to EBITDA for the twelve-month period ending on any given
date, to be
19
<PAGE> 22
greater than 3.0 to 1.0. Under the Amended Credit Facility, the Company's
failure to satisfy this covenant would give the banks the right to accelerate
any outstanding amounts. The Company anticipates that the banks will, if needed,
grant the Company a limited waiver from this covenant in part due to the
Company's expectation of satisfying this covenant after the MARINE 700 and
MARINE 500 are generating revenues under their existing contracts for several
months. There cannot be any assurance, however, that the Company will be able to
obtain any necessary bank waivers, or that any such breach of this financial
covenant will not have a material adverse effect on the Company's liquidity.
During 1997, the improvement in the offshore drilling market allowed
the Company to place some of its offshore rigs under longer term contracts. In
July 1997, the Company entered into a contract for the MARINE 500 that expires
on December 31, 2001 and is expected to produce total revenues of approximately
$154 million beginning May 1999, upon completion of a $120 million upgrade to
enable the rig to operate in water depths up to 5,000 feet. In December 1997,
the Company entered into a nine-month contract for the MARINE 510 that commenced
mid-May 1998 and was expected to generate revenues of $23 million. The MARINE
510 is being chartered from Shanghai Bureau of Marine Geological Survey for a
period of five years. Charter fees are payable only when the rig is under
contract. The contract included an early termination clause, which allowed the
customer to terminate the contract in mid-November 1998 for a fee of
approximately $1 million. The early termination caused the Company to realize
only approximately $15 million in revenues from the contract.
In January 1998, the Company obtained a three-year contract with an
option to extend to a five-year term for the MARINE 700. In June 1998 the
customer exercised the option and extended the contract to five years. The
contract is expected to generate aggregate dayrate revenues of approximately
$298 million over its five-year term, which is scheduled to begin late in the
second quarter of 1999 upon completion of the construction of MARINE 700 (see
"Construction of MARINE 700" discussion below). The contract also allows the
customer to terminate the contract if the rig is not available by July 15, 1999,
unless such delay is caused by the customer or any of its subcontractors.
Construction of MARINE 700. In December 1997, the company entered into
an agreement whereby HAM Marine, Inc. ("HAM") would complete construction of the
MARINE 700 semi-submersible drilling rig in their shipyard in Pascagoula,
Mississippi for $87 million. The shipyard contract calls for HAM to fabricate
certain components of the rig and install certain drilling equipment provided by
the Company ("Owner Furnished Equipment" or "OFE"). The shipyard contract calls
for monthly progress payments based on the percent complete.
The Company originally estimated that the OFE would cost approximately
$99 million including capitalized interest and other project management costs
resulting in a total estimated cost to complete the drilling rig of $186
million. Construction of the rig has progressed since the signing of the
shipyard contract and through December 31, 1998, the Company has paid HAM
approximately $60 million in progress payments and paid approximately $70
million for OFE and other related construction costs.
The shipyard contract initially contemplated a delivery date of
February 17, 1999. However, due to engineering, construction, weather and other
delays, the expected completion date for the MARINE 700 is now late second
quarter 1999. Additionally, the anticipated construction and outfitting cost has
increased to approximately $215 million. Included in the $29 million increase
over the original cost estimate are the cost of change orders initiated by Esso,
the Company's customer. Current estimates for the cost of these change orders is
approximately $5.7 million, which the Company will recover through an increase
in the dayrate during the term of the five-year drilling contract of
approximately $4,600 per day. See "Business -- Construction and Contract Risks"
for discussion of risks associated with the MARINE 700 contracts.
MARINE 500 Upgrade. In December 1997, the Company signed a contract
with Jurong to upgrade the MARINE 500 to fourth-generation capabilities for
approximately $38 million. Change orders have now increased the shipyard costs
to approximately $48 million. In addition to this $48 million, the Company
currently estimates that the OFE will cost approximately $72 million, including
capitalized interest and project management costs, resulting in a total
estimated cost to complete the drilling rig of $120 million. Through December
31, 1998, the Company has paid Jurong approximately $8 million in progress
payments and paid approximately $49 million for OFE and other related
construction costs. The contract anticipated that the rig would arrive in the
Singapore shipyard on July 15, 1998 and be completed by December 31, 1998. Since
the MARINE 500 did not arrive in the shipyard until October 13, 1998 due to an
extension of work under its previous drilling contract, the Company now expects
to complete construction of the
20
<PAGE> 23
MARINE 500 during the second quarter of 1999. See "Business Construction and
Contract Risks" for discussion of risks associated with the MARINE 500
contracts.
Capital Resources. During the year ended December 31, 1998 the Company
expended $190.9 million in capital expenditures consisting primarily of
disbursements for (i) the completion of the MARINE 700, (ii) the upgrade of the
MARINE 500, (iii) acquisition of the MARINE 306 and (iv) the purchase of drill
pipe and other rig machinery.
In December 1998, the Company acquired the MARINE 306 (formerly the
"Maersk Explorer"), a jack-up rig currently configured as an accommodation unit
for approximately $23 million. Currently, the rig is idle and is located in
Rotterdam. The Company anticipates marketing the rig as an accommodation unit.
If market conditions warrant, the rig can be upgraded to competitive drilling
status for approximately $50 million. An upgrade could be completed in
approximately nine months. If upgraded, the rig will be outfitted with the
drilling equipment removed from the MARINE 500 during its upgrade and will be
capable of operating in the North Sea.
The Company expects to spend approximately $160 million in 1999 for
capital expenditures, consisting primarily of expenditures to upgrade and
complete the MARINE 500 and MARINE 700.
The Company will continue to pursue acquisitions of additional drilling
rigs and related equipment and/or businesses. Future acquisitions, if any, would
likely be funded from the Company's working capital, the Amended Credit Facility
or through the issuance of debt and/or equity securities. The Company cannot
predict whether it will be successful in acquiring additional rigs, and
obtaining financing therefor, on acceptable terms. In addition, it is currently
anticipated that the Company will continue the upgrading of rigs to enhance
their capability to obtain longer-term contracts. The timing and actual amounts
expended by the Company in connection with its plans to upgrade and refurbish
selected rigs, as well as the type of rig modification comprising each program,
is subject to the discretion of the Company and will depend on the Company's
view of market conditions, the Company's cash flow, whether other acquisitions
are made, and other factors.
The Company anticipates that its available funds, together with cash
generated from operations and amounts that may be borrowed under the Amended
Credit Facility and other potential funding sources, such as increased credit
facilities and private or public debt or equity offerings, will be sufficient to
fund its required capital expenditures, working capital and debt service
requirements for the foreseeable future. Future cash flows, however, are subject
to a number of uncertainties, especially the condition of the oil and gas
industry. Accordingly, there can be no assurance that these resources will be
sufficient to fund the Company's cash requirements.
YEAR 2000 ISSUE
Currently, the Company utilizes third party software in all of its
computer applications. The Company's information systems personnel are currently
working with the third party vendors to resolve the potential problems
associated with the year 2000 and the processing of date sensitive information
by its computers and other systems. Based upon a continual evaluation and
working with software vendors, the Company has determined that upgrading its
existing accounting software to a current version will enable the computer
systems to function properly with respect to dates in the year 2000 and
thereafter, with minimal cost to the Company. This upgrade is expected to be
completed by mid-1999. The Company is still evaluating the effect of the Year
2000 on other computer systems and non-information technology systems, including
telephone systems, office and rig-based electronic equipment and devices with
embedded microprocessors. Additionally, the Company is currently contacting all
key vendors and suppliers to ensure that they have a Year 2000 compliance plan
in an effort to minimize the Company's exposure to their potential Year 2000
problems. The Company anticipates completion of its evaluation of
non-information technology equipment, key vendors and suppliers and any remedial
action and/or a contingency plan, if necessary, by mid-1999. With modifications
to existing software and conversions to new software, the Year 2000 issue is not
expected to pose significant operational problems for the Company's computer
systems. However, if such modifications or conversions are not made or are not
completed on time or if the Company's Year 2000 issues are more complicated or
costly than the Company currently estimates, the Year 2000 issue could have a
material adverse impact on the Company. The Company believes that it will be
able to implement successfully the changes necessary to address the Year 2000
issues with reliance on its third party vendors and does not expect the cost of
such changes to have a material impact on the Company's financial position,
results of operations or cash flows in future periods.
21
<PAGE> 24
STATEMENT OF FINANCIAL ACCOUNTING STANDARDS
In June 1998, the Financial Accounting Standards Board issued Statement
of Accounting Standards (SFAS) No. 133, "Accounting for Derivative Instruments
and Hedging Activities," which establishes standards for accounting for and
disclosure of derivative instruments and hedging activities. SFAS No. 133 is
effective for fiscal years beginning after June 15, 1999. The Company does not
expect SFAS No. 133 to have a material effect on its reported results.
FORWARD-LOOKING STATEMENTS
This Form 10-K, particularly the section entitled "Management's
Discussion and Analysis of Financial Condition and Results of Operations",
contains certain forward-looking statements within the meaning of Section 27A of
the Securities Act of 1933, as amended, and Section 21E of the Securities
Exchange Act of 1934, as amended, that are not historical facts concerning,
among other things, market conditions, the demand for offshore drilling
services, future acquisitions and fleet expansion, future financings, future rig
contracts, future capital expenditures including rig construction, upgrades and
refurbishments, and future results of operations. Actual results may differ
materially from those included in the forward-looking statements, and no
assurance can be given that the Company's expectations will be realized or
achieved. Important factors and risks that could cause actual results to differ
materially from those referred to in the forward-looking statements include (i)
a prolonged period of low oil or gas prices; (ii) the inadequacy of insurance
and indemnification to protect the Company against liability from all
consequences of well disasters, fire damage or environmental damage; (iii) the
inability of the Company to obtain insurance at reasonable rates; (iv) a
decrease in the demand for offshore drilling rigs especially in the U.S. Gulf of
Mexico or for slot jack-up rigs; (v) the risks attendant with operations in
foreign countries including actions that may be taken by foreign countries and
actions that may be taken by the United States against foreign countries; (vi)
the failure of the Company to successfully compete with the Company's
competitors that are larger and have a greater diversity of rigs and greater
financial resources than the Company; (vii) a decrease in rig utilization
resulting from reactivation of currently inactive non-marketed rigs or new
construction of rigs; (viii) the risks of delay and cost overruns attendant to
large construction projects such as the upgrade and refurbishment of certain of
the Company's rigs, including shortages of material or skilled labor,
engineering problems, latent defects or damage to current equipment, work
stoppages, weather interference and inability to obtain requisite permits or
approvals; (ix) the return of market and other conditions similar to those in
which the Company incurred net losses before extraordinary items for each of the
years ended December 31, 1991, 1992 and 1995; (x) the loss of key management
personnel or the inability of the Company to attract and retain sufficient
qualified personnel to operate its rigs; (xi) the renegotiation or cancellation
of the long-term contracts for the MARINE 700 or the MARINE 500, whether as a
result of the Company's failure to deliver the rig on time and in accordance
with contract specifications or because of some other reason; (xii) the adoption
of additional laws or regulations that limit or reduce drilling opportunities or
that increase the cost of drilling or increase the potential liability of the
Company; (xiii) the occurrence of risks attendant to contract drilling
operations including blowouts, cratering, fires and explosions, capsizing,
grounding or collision involving rigs while in operation, mobilization or
otherwise or damage to rigs from weather, sea conditions or unsound location;
(xiv) adverse uninsured litigation results; and (xv) adverse tax consequences
with respect to operations. These forward-looking statements speak only as of
the date of this Report. The Company expressly disclaims any obligation or
undertaking to release publicly any updates or revisions to any forward-looking
statement contained herein to reflect any change in the Company's expectations
with regard thereto or any change in events, conditions or circumstances on
which any statement is based.
22
<PAGE> 25
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Interest Rate Risk. The Company is subject to market risk exposure
related to changes in interest rates on its Amended Credit Facility. Interest on
borrowings under the Amended Credit Facility is at a pre-agreed upon percentage
point spread from either the prime interest rate or LIBOR. The Company may, at
its option, fix the interest rate for certain borrowings based on a spread over
LIBOR for 30 days to 6 months, with longer periods requiring bank approval. At
December 31, 1998, the Company had $50 million outstanding under its Amended
Credit Facility. Based upon this balance, an immediate change of one percent in
the interest rate would cause a change in interest expense of approximately
$500,000 on an annual basis. The Company's objective in maintaining these
variable rate borrowings is the flexibility obtained regarding early repayment
without penalties and lower overall cost as compared with fixed-rate borrowings.
Foreign Currency Exchange Rate Risk. The Company conducts business in
several foreign countries. Predominately all of its foreign operations are
denominated in U.S. dollars. The Company structures its drilling contracts in
U.S. dollars to mitigate its exposure to fluctuations in foreign currencies.
Other than some limited trade payables the Company does not currently have
financial instruments that are sensitive to foreign currency exchange rates.
23
<PAGE> 26
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEPENDENT AUDITORS' REPORT
The Board of Directors and Shareholders
Marine Drilling Companies, Inc.:
We have audited the consolidated balance sheets of Marine Drilling
Companies, Inc. and subsidiaries as of December 31, 1998 and 1997 and the
related consolidated statements of operations, shareholders' equity and cash
flows for each of the years in the three-year period ended December 31, 1998.
These consolidated financial statements are the responsibility of the Company's
management. Our responsibility is to express an opinion on these consolidated
financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above
present fairly, in all material respects, the financial position of Marine
Drilling Companies, Inc. and subsidiaries as of December 31, 1998 and 1997, and
the results of their operations and their cash flows for each of the years in
the three-year period ended December 31, 1998, in conformity with generally
accepted accounting principles.
KPMG LLP
Houston, Texas
January 26, 1999
24
<PAGE> 27
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS, EXCEPT SHARE DATA)
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------
1998 1997
--------- ---------
ASSETS
<S> <C> <C>
Current Assets:
Cash and cash equivalents $ 12,576 $ 20,619
Accounts receivable - trade and other, net 23,176 46,680
Prepaid expenses and other 3,290 4,592
Inventory 579 456
--------- ---------
Total current assets 39,621 72,347
Property and Equipment 500,510 310,122
Less accumulated depreciation 68,881 49,635
--------- ---------
Property and equipment, net 431,629 260,487
Other 4,434 1,348
--------- ---------
$ 475,684 $ 334,182
========= =========
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable $ 8,927 $ 6,367
Accrued expenses 20,667 7,824
Current tax liability 2,558 2,113
Employer's liability claims, current 770 571
--------- ---------
Total current liabilities 32,922 16,875
Long-term debt 50,000 --
Employer's liability claims, non-current and other 2,046 1,776
Deferred income taxes 29,128 18,090
Minority interest in subsidiary -- 1,699
Shareholders' Equity:
Common stock, par value $.01. Authorized 200,000,000 shares;
Issued and outstanding 52,365,537 and 51,890,444 shares as of
December 31, 1998 and December 31, 1997, respectively 524 519
Common stock restricted (1,596) (1,249)
Additional paid-in capital 206,603 201,236
Retained earnings from January 1, 1993 156,057 95,236
--------- ---------
Total shareholders' equity 361,588 295,742
--------- ---------
Commitments and contingencies -- --
--------- ---------
$ 475,684 $ 334,182
========= =========
</TABLE>
See notes to consolidated financial statements
25
<PAGE> 28
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<TABLE>
<CAPTION>
FOR THE YEARS ENDED DECEMBER 31,
----------------------------------------
1998 1997 1996
--------- ---------- ---------
<S> <C> <C> <C>
Revenues $ 228,015 $ 190,257 $ 110,329
Costs and Expenses:
Contract drilling 102,166 77,847 59,770
Depreciation and amortization 20,191 16,995 11,576
General and administrative 12,287 7,807 7,498
--------- --------- ---------
134,644 102,649 78,844
--------- --------- ---------
Operating income 93,371 87,608 31,485
--------- --------- ---------
Other Income (Expense):
Interest expense (481) (575) (895)
Interest income 1,683 2,398 1,261
Other income 968 405 405
--------- --------- ---------
2,170 2,228 771
--------- --------- ---------
Income before income taxes 95,541 89,836 32,256
Income tax expense 34,720 31,456 11,586
--------- --------- ---------
Net income $ 60,821 $ 58,380 $ 20,670
========= ========= =========
Earnings per share:
Basic $ 1.16 $ 1.13 $ 0.46
Diluted $ 1.15 $ 1.11 $ 0.45
Average common shares:
Basic 52,217 51,572 44,918
Diluted 52,726 52,452 45,748
</TABLE>
See notes to consolidated financial statements
26
<PAGE> 29
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY
YEARS ENDED DECEMBER 31, 1998, 1997 AND 1996
(IN THOUSANDS, EXCEPT SHARE DATA)
<TABLE>
<CAPTION>
COMMON STOCK
-----------------------------------------------
ISSUED IN TREASURY ADDITIONAL
----------------------------------------------- PAID-IN RESTRICTED RETAINED
SHARES AMOUNT SHARES AMOUNT CAPITAL STOCK EARNINGS
---------- --------- ---------- ----------- ---------- ----------- ----------
<S> <C> <C> <C> <C> <C> <C> <C>
Balances at December 31, 1995 44,169,643 $ 442 534,210 $ (2,016) $ 92,720 $ (505) $ 16,931
Net Income - - - - - - 20,670
Issuance of stock for stock offering 5,584,700 56 - - 79,109 - -
Issuance of stock for MARINE 305 882,352 9 - - 7,491 - -
Issuance of restricted common stock 80,833 1 - - 560 (561) -
Accrual of compensation expense - - - - - 438 -
Common stock options exercised 477,650 4 (484,120) 1,824 907 - (745)
Issuance of common stock for 401(k) 62,891 1 (50,090) 192 789 - -
Pre-quasi-reorganization net operating
loss carryforwards - - - - 834 - -
Tax benefits related to common stock
issued pursuant to long term
incentive plan - - - - 2,528 - -
Issuance of stock for Non-Employee
Directors' Plan 4,450 - - - 54 - -
----------- ------ -------- ---------- ---------- ---------- ----------
Balances at December 31, 1996 51,262,519 513 - - 184,992 (628) 36,856
Net income - - - - - - 58,380
Issuance of restricted common stock 76,500 - - - 1,323 (1,323) -
Accrual of compensation expense - - - - - 590 -
Forfeitures of restricted common stock (12,000) - - - (112) 112 -
Common stock options exercised 494,333 5 - - 1,370 - -
Issuance of common stock for 401(k) 66,277 1 - - 1,285 - -
Pre-quasi-reorganization net operating
loss carryforwards - - - - 8,310 - -
Tax benefits related to common stock
issued pursuant to long term
incentive plan - - - - 3,993 - -
Issuance of stock for Non-Employee
Directors' Plan 2,815 - - - 60 - -
Other - - - - 15 - -
----------- ------ -------- ---------- ---------- ---------- ----------
Balances at December 31, 1997 51,890,444 519 - - 201,236 (1,249) 95,236
Net income - - - - - - 60,821
Issuance of restricted common stock 76,900 1 - - 1,176 (1,177) -
Accrual of compensation expense - - - - - 659 -
Forfeitures of restricted common stock (10,000) - - - (171) 171 -
Common stock options exercised 272,675 3 - - 748 - -
Issuance of common stock for 401(k) 130,890 1 - - 1,670 - -
Tax benefits related to common stock
issued pursuant to long term
incentive plan - - - - 1,892 - -
Issuance of stock for Non-Employee
Directors' Plan 4,628 - - - 62 - -
Other - - - - (10) - -
----------- ------ -------- ---------- ---------- ---------- ----------
Balances at December 31, 1998 52,365,537 $ 524 - $ - $ 206,603 $ (1,596) $ 156,057
=========== ====== ======== ========== ========== ========== ==========
</TABLE>
See notes to consolidated financial statements.
27
<PAGE> 30
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS
(IN THOUSANDS)
<TABLE>
<CAPTION>
FOR THE YEARS ENDED DECEMBER 31,
---------------------------------------
1998 1997 1996
---------- --------- ---------
<S> <C> <C> <C>
Cash Flows From Operating Activities:
Net income $ 60,821 $ 58,380 $ 20,670
Adjustments to reconcile net income to net cash provided
By operating activities:
Deferred income taxes 11,038 4,361 7,585
Pre-quasi-reorganization net operating loss
carryforwards -- 8,310 834
Tax benefits related to common stock issued pursuant to
long-term incentive plan 1,892 3,993 2,528
Depreciation and amortization 20,191 16,995 11,576
Gain on disposition of equipment (884) (156) (410)
Accrual of compensation expense, net 659 590 438
Issuance of common stock to the employee
retirement plan and the Non-Employee Directors' Plan 1,733 1,345 1,036
(Increase) decrease in receivables 23,504 (25,286) (3,300)
(Increase) decrease in prepaid expenses, other and inventory 1,179 (2,690) 294
Increase (decrease) in payables, accrued
expenses and employer's liability claims 16,317 8,384 (1,344)
Other (3,342) (1,641) (627)
--------- --------- ---------
Net cash provided by operating activities 133,108 72,585 39,280
--------- --------- ---------
Cash Flows From Investing Activities:
Purchase of short-term investments -- (19,514) (9,729)
Maturity of short-term investments -- 29,967 --
Purchase of equipment (190,896) (73,490) (51,654)
Acquisition of company, net of cash acquired (2,519) (52,531) --
Proceeds from disposition of equipment 1,523 251 649
--------- --------- ---------
Net cash used in investing activities (191,892) (115,317) (60,734)
--------- --------- ---------
Cash Flows From Financing Activities:
Proceeds from long-term debt 50,000 -- 21,500
Proceeds from sale of common stock -- -- 79,582
Proceeds from exercise of stock options 751 1,375 1,990
Issuance cost of sale of common stock (10) 15 (417)
Payments of debt -- (10,000) (21,500)
--------- --------- ---------
Net cash provided by (used in) financing activities 50,741 (8,610) 81,155
--------- --------- ---------
Net increase (decrease) in cash and cash equivalents (8,043) (51,342) 59,701
Cash and cash equivalents at beginning of period 20,619 71,961 12,260
--------- --------- ---------
Cash and cash equivalents at end of period $ 12,576 $ 20,619 $ 71,961
========= ========= =========
</TABLE>
See notes to consolidated financial statements.
28
<PAGE> 31
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS - (CONTINUED)
(IN THOUSANDS, EXCEPT SHARE DATA)
<TABLE>
<CAPTION>
FOR THE YEARS ENDED DECEMBER 31,
-------------------------------------
1998 1997 1996
---------- --------- ---------
<S> <C> <C> <C>
SUPPLEMENTAL DISCLOSURE OF
CASH FLOW INFORMATION:
Cash paid during the period for:
Interest $ 553 $ 620 $ 956
Income taxes 21,345 11,835 640
Noncash investing and financing activities:
Issuance of 882,352 shares for MARINE 305 rig acquisition $ -- $ -- $ 7,500
Issuance of 76,900, 76,500 and 80,833 shares in 1998, 1997
and 1996 respectively, of restricted common stock 1,177 1,323 561
Forfeitures of 10,000 and 12,000 shares in 1998 and
1997 respectively, of restricted common stock (171) (112) --
Business acquisition, net of cash acquired:
Working capital, other than cash $ -- $ 766 $ --
Plant and equipment -- (54,186) --
Purchase price in excess of the net assets acquired -- (828) --
Minority interest (2,519) 1,717 --
-------- -------- --------
Net cash used for acquisition $ (2,519) $(52,531) $ --
======== ======== ========
</TABLE>
See notes to consolidated financial statements.
29
<PAGE> 32
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
YEARS ENDED DECEMBER 31, 1998, 1997 AND 1996
(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND ORGANIZATION
Organization and Business -- The consolidated financial statements
include the accounts of Marine Drilling Companies, Inc. ("Parent") and its
subsidiaries, Marine Drilling Management Company ("MDMC"), Marine 300 Series,
Inc. ("M300SI"), Marine Drilling International, Inc. ("MDII") and Marine
Drilling Companies (Norway) ASA ("MDCN ASA"). Unless the context otherwise
requires, the term "Company" refers to Marine Drilling Companies, Inc. and its
consolidated subsidiaries. Intercompany balances and transactions have been
eliminated in consolidation.
The Company is engaged in business of drilling offshore oil and gas
wells in domestic and international locations. International operations have
been conducted in India and Southeast Asia.
Inventory -- Inventory is carried at the lower of cost or market and
consists of operating supplies primarily for the Company's international
operations.
Property and Equipment --Property and equipment are stated at
historical cost or the cost assigned to the assets at December 31, 1992 in
connection with the adoption of quasi-reorganization accounting procedures.
Depreciation is provided on the straight-line method over the estimated
remaining useful lives of the assets as shown below:
<TABLE>
<CAPTION>
Years
-----------------
<S> <C>
Jack-up rigs (new)......................................... 20 to 25
Jack-up rigs (used/refurbished)............................ 5 to 15
Semi-submersible rigs (new)................................ 25
Semi-submersible rigs (used)............................... 10 to 15
Drill string............................................... 4
Other equipment............................................ 3 to 12
</TABLE>
Major renewals and improvements are capitalized and depreciated over
the respective asset's useful life. Expenditures for normal maintenance and
repairs are charged to expense as incurred. Maintenance and repairs amounted to
$12,345,000, $12,066,000 and $8,905,000 in 1998, 1997 and 1996, respectively.
When property or equipment is retired, the related assets and accumulated
depreciation are removed from the accounts and a gain or loss is reflected in
other income (expense). The Company continues to depreciate idle drilling
equipment using the same rates as while operating. The Company capitalizes
interest expense related to certain capital expenditure projects. Capitalized
interest was approximately $193,000, $49,000 and $61,000 for 1998, 1997, and
1996, respectively.
The Company reviews its long-lived assets and certain identifiable
intangible assets for impairment whenever events or certain changes in
circumstances indicate the carrying amount of an asset may not be recoverable.
Recoverability of assets to be held and used is measured by a comparison of the
carrying amount of an asset to future net cash flows expected to be generated by
the asset. If such assets are considered to be impaired, the impairment to be
recognized is measured by the amount by which the carrying amount of the assets
exceeds the fair value of the assets.
Employer's Liability Claims -- Employer's liability claims, principally
arising from actual or alleged personal injuries, are estimates of the Company's
liabilities for such occurrences. These claims are classified as current or
long-term based upon the periods in which such claims are expected to be funded.
Deferred Financing Costs -- Deferred financing costs are amortized over
the life of the related debt. Deferred financing costs, net of accumulated
amortization were $1,472,000, $783,000 and $231,000 at December 31, 1998, 1997
and 1996, respectively.
30
<PAGE> 33
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
Income Taxes -- Deferred tax assets and liabilities are recorded to
reflect the future tax consequences of differences between the financial
statement and tax bases of existing assets and liabilities. Deferred tax assets
and liabilities are measured using enacted tax rates expected to apply to
taxable income in the years in which those temporary differences are expected to
be recovered or settled. The effect on deferred tax assets and liabilities of a
change in tax rates is recognized in income in the period that includes the
enactment date.
Revenue Recognition -- Drilling revenues are recorded pursuant to day
rate contracts, under which the Company received a fixed amount per day for
providing drilling services with its rigs. Revenues are recognized as earned. In
connection with drilling contracts, the Company may receive lump sum fees for
mobilization of equipment and personnel or for capital improvements to rigs.
Significant mobilization and reimbursements are deferred and amortized over the
term of the drilling contract. There were no unamortized mobilization and
reimbursements as of December 31, 1998. As of December 31, 1997 there was
$2,433,000 of unamortized mobilization and reimbursement fees related to the
Marine 305 contract.
Rig Mobilization Costs -- When significant costs are incurred in
connection with mobilizing a drilling rig for a new contract, the Company defers
and amortizes such costs over the term of the applicable drilling contract.
There were no unamortized mobilization costs as of December 31, 1998 and
$2,487,000 unamortized mobilization costs at December 31, 1997. Mobilization
costs incurred in connection with rig purchases are capitalized as part of the
purchase price and are depreciated over the life of the rig.
Stock-Based Compensation -- Statement of Financial Accounting Standards
123 ("SFAS 123"), "Accounting for Stock-Based Compensation," encourages, but
does not require companies to record compensation costs for stock-based employee
compensation plans at fair value. The Company has chosen to continue to account
for stock-based compensation using the intrinsic value method prescribed in
Accounting Principals Board Opinion No. 25 "Accounting for Stock issued to
Employees," ("APB 25") and related interpretations. Accordingly, compensation
cost for stock options is measured as the excess, if any, of the quoted market
price of the Company's stock at the date of grant over the amount the employee
must pay to acquire the stock. The disclosures required by SFAS 123, however,
have been included in Note 8.
Cash and Cash Equivalents -- The Company generally considers all highly
liquid investments purchased with an original maturity of three months or less
to be cash equivalents. At December 31, 1998, none of the Company's cash on hand
was restricted. At December 31, 1997, $5,000,000 of the Company's cash on hand
was restricted as a result of cash collateral requirements related to a credit
facility used for issuing letters of credit to support the Company's
international activities. As of December 31, 1998 and 1997, letters of credit
totaling $908,000 and $2,500,000, respectively, were outstanding.
Treasury Stock -- Treasury stock is acquired under the cost method and
valued upon reissuance using the first-in, first-out method. During 1995, the
Company purchased 735,633 shares of common stock at an aggregate cost of
$2,659,000. In addition, during 1995, the Company reissued 201,423 shares at an
aggregate cost of $643,000 for the employee and non-employee benefit plans. No
shares were repurchased during 1996, however, 534,210 shares were reissued at an
aggregate cost of $2,016,000 for the employee and non-employee benefit plans. At
December 31, 1998, the Company had remaining authorization under the stock
purchase program to acquire up to 4,000,000 shares.
Capital Structure -- The Company has one class of common stock, par
value $0.01. The stock is traded on the NYSE Stock Market under the symbol MRL.
There are 200,000,000 authorized shares of which 52,365,537 were issued and
outstanding as of December 31, 1998. Each share of common stock is allowed one
voting right.
Earnings Per Share -- Effective December 1997 the Company was required
to adopt Statement of Financial Accounting Standards No. 128, "Earnings per
Share" ("SFAS 128"). SFAS 128 introduces the concept of basic earnings per
share, which represents net income divided by the weighted average common shares
outstanding without the dilutive effects of common stock equivalents (options,
warrants, etc). Common stock equivalents with a weighted average of 509,000,
880,000 and 830,000 are reflected in the calculation of diluted earnings per
share for the years ended December 31, 1998, 1997 and 1996, respectively. There
were 849,000 and 250,000 stock options outstanding for the years ended December
31, 1998 and 1996, respectively, which were not included in the computation of
diluted
31
<PAGE> 34
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
earnings per share because the exercise price of these options was greater than
the average market price of the common shares. For the year ended December 31,
1997, there were no stock options outstanding that were not included in the
computation of diluted earnings per share. No adjustment to net income was made
in calculating diluted earnings per share for the years ended December 31, 1998,
1997 and 1996.
Reclassification of Accounts -- Certain reclassifications have been
made to conform to current year presentation with no effect on net income.
Concentrations of Credit Risk -- The market for the Company's services
and products is the offshore oil and gas industry, and the Company's customers
consist primarily of independent and major oil and gas companies. The Company
performs ongoing credit evaluations of its customers and obtains collateral
security as deemed prudent. The Company has established an adequate allowance
for bad debts, and such losses have historically been within management's
expectations (see Note 11). At December 31, 1998, 1997 and 1996, the Company had
cash deposits in one bank. In addition, the Company had mutual funds and
commercial paper with a variety of companies and financial institutions with
strong credit ratings, and such securities are held until maturity. The Company
believes that credit and market risk in such instruments is minimal.
Fair Values of Financial Instruments -- The fair values of the
Company's cash equivalents, trade receivables and trade payables approximated
their carrying values due to the short-term maturities of these instruments. The
estimated fair value of long-term debt is equivalent to its carrying value due
to the floating interest rate (see Note 5).
Use of Estimates -- Management of the Company has made a number of
estimates and assumptions relating to the reporting of assets and liabilities
and the disclosure of contingent assets and liabilities to prepare these
financial statements in conformity with generally accepted accounting
principles. Actual results could differ from those estimates.
(2) ACCOUNTS RECEIVABLE - TRADE AND OTHER, NET
Accounts receivables are summarized as follows (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------
1998 1997
------------- -------------
<S> <C> <C>
Trade receivables......................................................... $ 22,714 $ 38,613
Marine 15 fire insurance claim............................................ - 7,175
Other receivables......................................................... 462 892
----------- -----------
$ 23,176 $ 46,680
=========== ===========
</TABLE>
(3) PROPERTY AND EQUIPMENT
Property and equipment are stated at historical cost or the cost
assigned to the assets at December 31, 1992 in connection with the adoption of
quasi-reorganization accounting procedures, and are summarized as follows (in
thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------
1998 1997
------------- -------------
<S> <C> <C>
Drilling rigs............................................................. $ 292,003 $ 209,483
Drill string.............................................................. 8,622 6,517
Other equipment........................................................... 6,611 5,377
Construction in progress.................................................. 193,274 88,745
------------ ------------
$ 500,510 $ 310,122
============ ============
</TABLE>
Depreciation expense was $19,984,000, $16,631,000, and $11,530,000 for
the years ended December 31, 1998, 1997 and 1996, respectively.
32
<PAGE> 35
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
(4) ACCRUED EXPENSES
Accrued expenses are summarized as follows (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
-----------------------------
1998 1997
------------- ------------
<S> <C> <C>
Construction in progress.................................................. $ 11,320 $ 43
Accrued payroll and related taxes......................................... 3,491 2,439
Accrued health benefit plan claims........................................ 740 530
Foreign tax liability..................................................... 1,963 845
Other accrued expenses.................................................... 3,153 3,967
------------ ------------
$ 20,667 $ 7,824
============ ============
</TABLE>
(5) LONG-TERM DEBT
In March 1997, the Company entered into a credit agreement ("Credit
Facility") with certain banks providing financing up to $100 million to be used
for rig acquisitions and upgrades. This agreement included a revolving credit
facility available through December 31, 1999, at which point it converted into a
four-year term loan. The Credit Facility called for interest and facility fees
to be paid quarterly during the terms of both facilities. The term loan facility
provided for principal payments quarterly in equal installments beginning March
31, 2000. Interest accrues at a rate of (i) London Interbank Offered Rate
("LIBOR") plus a margin of .75% to 1.25% or (ii) prime plus a margin of 0% to
.50%, with margins determined pursuant to a debt to capital calculation. The
borrowings were secured by all of the Company's rig fleet, except for the MARINE
700, as well as certain other assets. In connection with the consummation of the
Credit Facility, the Company repaid and terminated its former $35 million credit
facility with a U.S. financial institution.
On August 12, 1998, the Company entered into an agreement (the "Amended
Credit Facility") with a consortium of domestic and international banks, which
amends the Credit Facility to a five-year revolver, eliminates the term loan
conversion feature and increases the credit line to $200 million. The Amended
Credit Facility is secured by substantially all of the Company's assets,
including its rig fleet. The Company and its subsidiaries will be required to
comply with various covenants and restrictions, including, but not limited to,
the maintenance of financial ratios and the restriction on payments of
dividends. Interest will accrue at a rate of (i) LIBOR plus a margin of .75% to
1.25% with margins determined pursuant to a debt to EBITDA calculation or (ii)
prime if a Base Rate Loan. As of December 31, 1998, $50,000,000 was outstanding
under the Amended Credit Facility.
(6) INCOME TAXES
Income taxes consist of the following (in thousands):
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31,
---------------------------------------------
1998 1997 1996
---------- --------- ---------
<S> <C> <C> <C>
Current:
U.S. federal........................................... $ 17,876 $ 12,197 $ 343
State.................................................. 48 44 -
Foreign................................................ 3,866 2,551 296
---------- --------- ---------
21,790 14,792 639
---------- --------- ---------
Other:
U.S. federal - deferred................................ 11,038 4,361 7,585
Pre-quasi-reorganization net operating loss
carryforwards...................................... - 8,310 834
Tax benefits related to common stock issued
pursuant to long-term incentive plan............... 1,892 3,993 2,528
---------- --------- ---------
12,930 16,664 10,947
---------- --------- ---------
Total tax expense............................................ $ 34,720 $ 31,456 $ 11,586
========== ========= =========
</TABLE>
33
<PAGE> 36
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
As a result of the adoption of quasi-reorganization accounting
procedures on December 31, 1992, the tax effect of the realization of tax
attributes generated prior thereto are recorded directly to shareholders' equity
as an adjustment to additional paid-in capital and are not reflected as a
reduction of income tax expense. The realization of tax attributes prior to the
quasi-reorganization are subject to the rules and guidance of the Internal
Revenue Service and United States Department of the Treasury as interpreted or
applied to situations similar to the Company.
For the years ended December 31, 1998, 1997 and 1996, the effective tax
rates for financial reporting purposes of 36%, 35% and 36%, respectively,
approximates the U.S. federal statutory rates of 35%, 35% and 35%. The effective
rate was higher than the statutory rate in 1998 and 1996 due to the effect of
foreign tax payments for which the Company did not receive U.S. federal tax
benefit.
The tax effects of temporary differences that give rise to significant
portions of the deterred tax assets and deferred tax liabilities at December 31,
1998 and 1997 are presented below (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31,
----------------------
1998 1997
-------- --------
<S> <C> <C>
Deferred tax assets:
Net operating loss carryforwards .................. $ 3,775 $ 13,087
Alternative minimum tax carryforward .............. -- 688
Investment tax, general business and foreign tax
credit carryforwards .......................... 291 442
Employer's liability claims ....................... 863 733
Deferred compensation ............................. 119 --
Allowance for bad debts ........................... 456 53
-------- --------
Total gross deferred tax assets ................... 5,504 15,003
Less valuation allowance .......................... (4,066) (14,270)
-------- --------
Net deferred tax assets ........................... 1,438 733
-------- --------
Deferred tax liabilities:
Plant and equipment, principally due to differences
in depreciation ............................... 30,001 17,929
Deferred expenses ................................. 119 766
Deferred intercompany gains and losses ............ 446 128
-------- --------
Total gross deferred tax liabilities .............. 30,566 18,823
-------- --------
Net deferred tax liability ............................. $ 29,128 $ 18,090
======== ========
</TABLE>
The valuation allowance for deferred tax assets as of December 31, 1998
and 1997 was $4,066,000 and $14,270,000 respectively. The net change in the
total valuation allowance for the years ended December 31, 1998 and 1997 was a
decrease of $10,204,000 and $14,710,000 respectively. In assessing the
realizability of deferred tax assets, management considers whether it is more
likely than not that some portion or all of the deferred tax assets will not be
realized. Management considers the scheduled reversal of deferred tax
liabilities, projected future taxable income, and tax planning strategies in
making this assessment. Based upon projections for future taxable income over
the periods which the deferred tax assets are deductible and the Section 382
limitation as discussed below, management believes it is more likely than not
that the Company will realize the benefits of these deductible differences, net
of the existing valuation allowances at December 31, 1998.
At December 31, 1998, the Company had net operating loss carryforwards
for federal income tax purposes of $10,787,000, which if not utilized, expire in
years 2006 through 2011. The Company also had investment tax credit and general
business credit carryforwards for federal income tax purposes of approximately
$291,000 at December 31, 1998, which if not utilized, expire in years 1999 to
2000. In late 1995 and early 1996, certain venture capital firms holding
significant percentages of the Company's common stock sold or distributed their
positions. These transactions triggered an ownership change pursuant to Section
382 in March 1996. As a result of this ownership
34
<PAGE> 37
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
change, the Company's use of its net operating loss, investment tax credit and
general business credit carryforwards subsequent to that date will be limited.
(7) BENEFIT PLANS
1992 LONG TERM INCENTIVE PLAN -- In late 1992, the Company adopted the
Marine Drilling 1992 Long Term Incentive Plan ("1992 Plan") which was amended in
1996. Pursuant to the terms of the 1992 Plan, an aggregate of 10,000,000 shares
(subject to the restrictions described herein) of common stock are available for
distribution pursuant to stock options, SARs and restricted stock. The number of
shares of common stock available for distribution is further limited in that no
stock options, SARs or restricted stock may be issued if, immediately after such
issuance, the number of shares subject to outstanding stock options, SARs and
restricted stock awards would exceed 5% of the common stock then outstanding.
The shares of common stock subject to any stock option or SAR that terminates
without a payment being made in the form of common stock would again become
available for distribution pursuant to the 1992 Plan.
Restricted Common Stock. During 1998, 1997 and 1996, the Company issued
restricted stock grants consisting of 76,900, 76,500 and 80,833 shares,
respectively, of common stock. These grants generally lapse over four-year
periods and the values of the grants are based on the respective closing prices
on the day preceding each grant and are recognized as compensation expense over
the periods during which the restrictions lapse. Compensation expense related to
the issuance of restricted common stock for the years ended December 31, 1998,
1997 and 1996 was $648,000, $590,000 and $438,000, respectively. During 1998 and
1997, 10,000 and 12,000 shares, respectively, of restricted common stock were
forfeited. No restricted common stock was forfeited during 1996.
Common Stock Options. The exercise price of each option equals the
market price of the Company's stock on the date of grant. An option's maximum
term is ten years. The vesting period ranges from immediately to four years.
This period is determined at the issuance of each grant. The following table
summarizes stock option transactions pursuant to the 1992 Plan:
<TABLE>
<CAPTION>
1998 1997 1996
------------------------ --------------------- ------------------------
WEIGHTED 50 WEIGHTED WEIGHTED
AVERAGE AVERAGE AVERAGE
EXERCISE EXERCISE EXERCISE
FIXED OPTIONS SHARES PRICE SHARES PRICE SHARES PRICE
- ------------------------------------ ---------- -------- ---------- -------- ---------- ----------
<S> <C> <C> <C> <C> <C> <C>
Outstanding at beginning of year 1,299,547 $ 7.80 1,721,380 $ 5.63 1,880,650 $ 2.08
Granted 831,500 17.63 117,500 16.38 802,500 9.68
Exercised (245,175) 2.56 (489,333) 2.77 (961,770) 2.07
Forfeited (108,334) 15.74 (50,000) 2.50 --
---------- --------- -----------
Outstanding at year end 1,777,538 $ 12.64 1,299,547 $ 7.80 1,721,380 $ 5.63
========== ========= ===========
Options exercisable at year-end 662,079 473,714 573,880
Weighted-average fair value
of options granted during the year $ 10.94 $ 9.55 $ 5.74
</TABLE>
The following table summarizes information about fixed-price stock
options outstanding and exercisable at December 31, 1998:
<TABLE>
<CAPTION>
OPTIONS OUTSTANDING OPTIONS EXERCISABLE
------------------------------------------------------ -------------------------------
NUMBER WEIGHTED-AVG. NUMBER
OUTSTANDING REMAINING WEIGHTED-AVG. EXERCISABLE WEIGHTED-AVG.
EXERCISE PRICES AT 12/31/98 CONTRACTUAL LIFE EXERCISE PRICE AT 12/31/98 EXERCISE PRICE
--------------------- --------------- ---------------- ---------------- ------------ ----------------
<S> <C> <C> <C> <C> <C>
$ 1.25 to 2.50 192,705 5.6 years $ 2.20 122,705 $ 2.03
$ 6.00 to 9.44 675,000 7.9 years 9.02 368,333 8.94
$10.00 to 18.13 734,833 8.7 years 16.13 171,041 13.45
$22.56 to 24.63 175,000 9.3 years 23.42 - -
--------- -------
1,777,538 8.1 years $ 12.64 662,079 $ 8.82
========= =======
</TABLE>
35
<PAGE> 38
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
Based upon common stock outstanding as of December 31, 1998 and 1997
and shares reserved for issuance as set forth above, the number of shares then
available for future stock options, SARs and restricted stock grants was
7,217,709 and 7,537,284 shares, respectively. The number of shares available due
to the 5% limitation was 809,279 and 1,273,730 shares, respectively.
No compensation costs were recognized in income for 1998, 1997 and 1996
because the Company has elected to continue accounting for such transactions
under APB 25.
NON-EMPLOYEE DIRECTORS' PLAN -- The Company adopted the 1995
Non-Employee Directors' Plan (the "Directors' Plan") effective June 29, 1995.
The Directors' Plan provides for the grant of shares and options to acquire
common stock to each director who is not an employee of the Company. A maximum
of 350,000 shares may be issued pursuant to stock awards or options. Each option
granted will vest and become exercisable one year after its grant and will
expire ten years from the date the option is granted. The exercise price of each
option equals the market price of the Company's stock on the date of grant. No
compensation costs were recognized in income.
The following table summarizes stock option transactions under the
Director's Plan as of December 31, 1998:
<TABLE>
<CAPTION>
1998 1997 1996
------------------------ ---------------------- ---------------------
WEIGHTED WEIGHTED WEIGHTED
AVERAGE AVERAGE AVERAGE
EXERCISE EXERCISE EXERCISE
FIXED OPTIONS SHARES PRICE SHARES PRICE SHARES PRICE
-------------------------------- ----------- ---------- --------- --------- --------- ---------
<S> <C> <C> <C> <C> <C> <C>
Outstanding at beginning of year 67,500 $ 6.99 60,000 $ 4.94 50,000 $ 4.00
Granted 40,000 21.63 12,500 15.63 10,000 9.63
Exercised (27,500) 4.51 (5,000) 4.00 - -
Forfeited (7,500) 13.63 - - - -
-------- --------- -------
Outstanding at year-end 72,500 $ 15.31 67,500 $ 6.99 60,000 $ 4.94
======== ========= =======
Options exercisable at year-end 32,500 55,000 50,000
Weighted-average fair value of
Options granted during the year $ 13.37 $ 9.08 $ 5.79
</TABLE>
The following table summarizes information about fixed-price stock
options outstanding and exercisable at December 31, 1998 under the Director's
Plan.
<TABLE>
<CAPTION>
OPTIONS OUTSTANDING OPTIONS EXERCISABLE
----------------------------------------------------- ---------------------------------
NUMBER WEIGHTED-AVG. NUMBER
OUTSTANDING REMAINING WEIGHTED-AVG. EXERCISABLE WEIGHTED-AVG.
EXERCISE PRICES AT 12/31/98 CONTRACTUAL LIFE EXERCISE PRICE AT 12/31/98 EXERCISE PRICE
--------------- ----------- ---------------- -------------- ----------- --------------
<S> <C> <C> <C> <C> <C>
$ 4.00 to 9.63 25,000 6.6 years $ 5.13 25,000 $ 5.13
$15.63 to 17.88 17,500 8.7 years 16.91 7,500 15.63
$22.88 30,000 9.4 years 22.88 - -
--------- ---------
72,500 7.8 years $ 15.31 32,500 $ 7.55
========= =========
</TABLE>
During 1998 and 1997, 4,628 and 2,815 shares were issued as stock
awards and related compensation expense of $169,000 and $151,000 was recognized
in 1998 and 1997, respectively.
EMPLOYEE 401(k) PROFIT SHARING PLAN -- The Company has a 401(k) Profit
Sharing Plan (the "401(k) Plan") covering substantially all of its employees who
have been employed at least three months. The Company matches employees'
contributions to the Plan on a dollar-for-dollar basis, in the form of Company
common stock, up to 6% of
36
<PAGE> 39
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
their eligible compensation. During 1998, 1997 and 1996, the Company made
matching contributions with the Company's common stock totaling $1,704,000,
$1,303,000 and $1,014,000, respectively.
EXECUTIVE DEFERRED COMPENSATION PLAN -- The Company adopted the
Executive Deferred Compensation Plan (the "Executive Plan") effective December
31, 1994. Employees who participate in the Executive Plan are selected by an
Administrative Committee. Under the Executive Plan, the participating executives
may elect (i) to defer up to 80% of compensation after reaching the limitations
applicable to the Company's 401(k) Plan and (ii) to defer any excess
contributions refunded by the 401(k) Plan. The Company matches executives'
contributions to the Executive Plan on a dollar-for-dollar basis, in cash up to
6% of their eligible compensation. As of December 31, 1998, and 1997 the amount
deferred under the Executive Plan was $338,000 and $252,000, respectively.
(8) ACCOUNTING FOR STOCK-BASED COMPENSATION
The Company has adopted the disclosure-only provisions of SFAS 123,
"Accounting for Stock-Based Compensation." Accordingly, no compensation cost has
been recognized for its fixed stock option plans. If the Company had elected to
recognize compensation cost based on the fair value of the options at the grant
date as prescribed by SFAS 123, net income and net income per share would
approximate the pro forma amounts indicated below (in thousands except per
share data):
<TABLE>
<CAPTION>
1998 1997 1996
------------- -------------- -------------
<S> <C> <C> <C>
Net income:
As reported......................................... $ 60,821 $ 58,380 $ 20,670
Pro forma........................................... 57,677 56,988 19,497
Basic earnings per share:
As reported......................................... 1.16 1.13 0.46
Pro forma........................................... 1.10 1.11 0.43
Diluted earnings per share:
As reported......................................... 1.15 1.11 0.45
Pro forma........................................... 1.09 1.09 0.43
</TABLE>
The fair value of each option grant is estimated on the date of grant
using the Black-Scholes option-pricing model with the following weighted average
assumptions.
<TABLE>
<CAPTION>
1998 1997 1996
------------- -------------- -------------
<S> <C> <C> <C>
Expected dividend yield.................................. - - -
Expected price volatility................................ 70.0% 63.2% 63.8%
Risk-free interest rate.................................. 5.3% 5.4% 6.2%
Expected life of option.................................. 5 years 5 years 5 years
</TABLE>
The effects of applying SFAS 123 in the pro forma disclosure are not
indicative of future amounts. SFAS 123 does not apply to awards prior to 1995,
and additional awards in future years were not anticipated in the calculations.
(9) SHAREHOLDERS RIGHTS PLAN
The Company adopted a shareholder rights plan on November 8, 1996,
designed to assure that the Company's shareholders receive fair and equal
treatment in the event of any proposed takeover of the Company and to guard
against partial tender offers and other abusive takeover tactics to gain control
of the Company without paying all shareholders a fair price. The rights plan was
not adopted in response to any specific takeover proposal. Under the rights
plan, the Company issued one preferred share purchase right (a "Right") with
respect to each outstanding share of common stock outstanding on November 20,
1996. Each Right entitles the registered holder to purchase from the Company one
one-thousandth of a share of Junior Participating Preferred Stock, $.01 par
value per share (the "Preferred Shares"), of the Company at a price of $56.00
per one one-thousandth of a Preferred Share, subject to adjustment. The Rights
are not currently exercisable and will become exercisable only in the event a
person or group acquires beneficial
37
<PAGE> 40
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
ownership of 15% or more of the Company's common stock. Each whole Preferred
Share will be entitled to receive a quarterly preferential dividend in an amount
per share equal to the greater of (i) $1.00 in cash or (ii) in the aggregate,
1,000 times the dividend declared on the common stock. In the event of
liquidation, the holders of the Preferred Shares will be entitled to receive a
preferential liquidation payment equal to the greater of (i) $1,000 per share or
(ii) in the aggregate, 1,000 times the payment made on the shares of common
stock. In the event of any merger, consolidation or other transaction in which
shares of common stock are exchanged for or changed into other stock or
securities, cash or other property, each whole Preferred Share will be entitled
to receive 1,000 times the amount received per share of common stock. Each whole
Preferred Share shall be entitled to 1,000 votes on all matters submitted to a
vote of the shareholders of the Company, and Preferred Shares shall generally
vote together as one class with the common stock and any other capital stock on
all matters submitted to a vote of shareholders of the Company. The Rights will
expire on November 19, 2006 (the "Final Expiration Date"), unless the Final
Expiration Date is extended or the Rights are earlier redeemed or exchanged by
the Company.
(10) COMMITMENTS AND CONTINGENCIES
India Lawsuit -- Jagson International Limited ("Jagson"), an Indian
entity, has brought suit against Marine Drilling Companies, Inc. and Marine 300
Series, Inc. The plaintiff has alleged that the Company agreed to charter two
jack-up rigs to the plaintiff during 1992 and that it breached the agreement by
failing to charter the rigs resulting in damages in excess of $14,500,000. In
August 1995, Jagson filed a suit against the Company in New Delhi, India that
was subsequently withdrawn and filed a second suit in New Delhi against the
Company in October 1995 that was dismissed by the court. In May 1996, Jagson
filed a third suit against the Company in Bombay, India for the same claim and
attempted to attach the MARINE 201, located in India at the time, to the claim.
In March 1998, the court dismissed the motion for attachment. Although the third
suit is still on file with the court, the MARINE 201 is no longer in India and
there have been no further proceedings in the lawsuit. The Company disputes the
existence of the agreement and intends to vigorously defend the suit. The
Company does not believe this dispute will have a material adverse effect on its
results of operations or financial condition.
Legal Proceedings -- The Company is involved in various other claims
and legal actions arising in the ordinary course of business. In the opinion of
management, the ultimate disposition of these matters will not have a material
adverse effect on the Company's consolidated financial position, results of
operations or liquidity.
Operating Leases -- The Company rents certain equipment and other
property under operating leases. Rental expense was $1,722,000, $1,836,000 and
$2,208,000 in 1998, 1997 and 1996, respectively. Aggregate future minimum rental
payments relating to operating leases not including the charter fee for the
MARINE 510, are as follows (in thousands):
<TABLE>
<CAPTION>
1999 2000 2001 2002 2003
------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C>
Office and equipment leases.................... $ 702 $ 452 $ 302 $ 294 $ 291
======= ======= ======= ======= ======
</TABLE>
Shipyard Contracts -- In December 1997, the company entered into an
agreement whereby HAM Marine, Inc. ("HAM") would complete construction of the
MARINE 700 semi-submersible drilling rig in their shipyard in Pascagoula,
Mississippi for $87,000,000. The shipyard contract calls for HAM to fabricate
certain components of the rig and install certain drilling equipment provided by
the Company ("Owner Furnished Equipment" or "OFE"). The shipyard contract calls
for monthly progress payments based on the percent complete.
The Company originally estimated that the OFE would cost approximately
$99,000,000 including capitalized interest and other soft costs resulting in a
total estimated cost to complete the drilling rig of $186,000,000. Construction
of the rig has progressed since the signing of the shipyard contract and through
December 31, 1998, the Company has paid HAM approximately $60,000,000 in
progress payments and incurred approximately $70,000,000 for OFE and other
related construction costs.
38
<PAGE> 41
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
The shipyard contract initially contemplated a delivery date of
February 17, 1999. However, due in part to three tropical storms along the
Mississippi Gulf Coast, including Hurricane Georges, and engineering and
construction delays, the expected completion date for the MARINE 700 is now late
second quarter 1999. Additionally, due to the delays, the anticipated
construction and outfitting cost has increased to approximately $215 million.
Included in the $29 million increase over the original cost estimate is the cost
of change orders initiated by Esso, the Company's customer. Current estimates
for the cost of these change orders is approximately $5,700,000, which the
Company will recover through an increase in the dayrate during the term of the
five-year drilling contract of approximately $4,600 per day.
In December 1997, the Company signed a contract with Jurong to upgrade
the MARINE 500 to fourth-generation capabilities for approximately $38 million.
Change orders have now increased the shipyard costs to approximately $48
million. In addition to this $48 million, the Company currently estimates that
the OFE will cost approximately $72 million, including capitalized interest and
project management costs, resulting in a total estimated cost to complete the
drilling rig of $120 million. Through December 31, 1998, the Company has paid
Jurong approximately $8 million in progress payments and incurred approximately
$49 million for OFE and other related construction costs. The contract
anticipated that the rig would arrive in the Singapore shipyard on July 15, 1998
and be completed by December 31, 1998. Since the MARINE 500 did not arrive in
the shipyard until October 13, 1998 due to an extension of work under its
previous drilling contract, the Company now expects to complete construction of
the MARINE 500 during the second quarter of 1999.
Charter Agreement -- In July 1997, the Company entered into a Charter
Agreement with SBMGS to charter the KANTAN 3 (now referred to as the MARINE
510), a semi-submersible rig, for a period of five years. The MARINE 510 is a
600-foot water depth rig based upon the Pacesetter design and was built in China
in 1984. The Charter Agreement began in mid-May 1998. The Charter Agreement and
related agreements require us to pay approximately $26,000 per day during the
first year, $23,000 per day during the second year and $24,500 per day for the
last three years of the charter for each day that the MARINE 510 is working. The
MARINE 510 is currently idle in Singapore. In January 1999, the Company reached
a letter agreement with SBMGS, subject to a definitive agreement, to amend the
Charter. This amendment will allow for a variable charter hire fee equal to 60%
of rig operating profit (dayrate revenue less operating expenses) and provides
an option for the Company to extend the Charter for up to five years beyond the
original five year term.
Marketing Agreement for NANHAI VI. In August 1998, the Company entered
into an agreement effective through October 1, 1999, with China's Southern
Drilling Company to market and manage the 1500-foot water depth rated
semi-submersible NANHAI VI. The NANHAI VI is a self-propelled, semi-submersible
drilling rig, which was built in 1982 and modified and refurbished in 1995. The
rig is technically and economically suitable to be upgraded to 4,000-foot water
depth capability. Estimated total lead time required to secure the equipment
needed for the upgrade, complete the project and move the rig to first drilling
location is one year. If the rig is required to be upgraded, the cost of the
upgrade will be funded by the owner. The Company is actively marketing the rig,
which is currently working, but would be made available by Southern Drilling
Company upon consummation of a mutually agreeable drilling contract.
(11) SEGMENT AND RELATED INFORMATION
In 1997, the Financial Accounting Standards Board issued Statement No.
131 "Disclosures about Segments of an Enterprise and Related Reporting" (SFAS
131). As required the Company has adopted SFAS 131. For reporting purposes the
Company defines its segments as shallow water drilling (jack-up rigs) and
deepwater drilling (semi-submersibles). The accounting policies of the
reportable segments are the same as those described in Note 1 of Notes to
Consolidated Financial Statements. The Company evaluates the performance of its
operating segments based on income before taxes and non-recurring items.
Operating income consists of revenues less the related operating costs and
expenses, including depreciation and allocated operation support, excluding
interest and unallocated corporate expenses. Identifiable assets by operating
segment include assets directly identified with those operations.
39
<PAGE> 42
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
The following table sets forth consolidated financial information with
respect to the Company and its subsidiaries by operating segment (in thousands):
<TABLE>
<CAPTION>
JACK-UP SEMI CORPORATE &
OPERATIONS OPERATIONS OTHER TOTAL
------------- ------------ ------------- ----------
<S> <C> <C> <C> <C>
1998
Revenues $ 192,667 $ 35,348 $ -- $ 228,015
Operating Income (Loss) 97,714 10,940 (15,283) 93,371
Identifiable Assets 166,622 280,684 28,378 475,684
Capital Expenditures 27,368 158,267 5,261 190,896
Depreciation & Amortization 13,923 3,272 2,996 20,191
1997
Revenues $ 172,143 $ 18,114 $ -- $ 190,257
Operating Income (Loss) 93,276 4,632 (10,300) 87,608
Identifiable Assets 179,584 123,280 31,318 334,182
Capital Expenditures 39,574 84,366 3,736 127,676
Depreciation & Amortization 11,260 3,242 2,493 16,995
1996
Revenues $ 110,329 $ -- $ -- $ 110,329
Operating Income (Loss) 40,980 (333) (9,162) 31,485
Identifiable Assets 126,810 38,092 90,045 254,947
Capital Expenditures 17,967 38,062 3,125 59,154
Depreciation & Amortization 9,912 -- 1,664 11,576
</TABLE>
The Company also provides services in both domestic and foreign
locations. The following table sets forth financial information with respect to
the Company and its subsidiaries by geographic area (in thousands):
<TABLE>
<CAPTION>
1998 1997 1996
----------- ---------- ----------
<S> <C> <C> <C>
Revenues:
United States $ 161,974 $ 157,349 $ 104,969
India 4,585 5,381 5,360
Southeast Asia 61,456 27,527 -
Other Foreign - - -
Long-Lived Assets:
United States 264,550 158,432 87,193
India - 13,214 14,195
Southeast Asia 131,959 88,841 38,062
Other Foreign 35,120 - 9,287
</TABLE>
The Company negotiates drilling contracts with a number of customers
for varying terms, and management believes it is not dependent upon any single
customer. For the years 1998, 1997 and 1996, sales to customers that represented
10% or more of consolidated drilling revenues were as follows (in thousands):
<TABLE>
<CAPTION>
1998 1997 1996
-------------------------- ------------------------- --------------------------
% OF TOTAL % OF TOTAL % OF TOTAL
REVENUE REVENUE REVENUE REVENUE REVENUE REVENUE
----------- ------------ --------- ---------- ----------- -------------
<S> <C> <C> <C> <C> <C>
Customer A - Jack-up Operations $ 13,772 * $ 11,371 * $ 20,461 19%
Customer B - Jack-up Operations 54,381 24% 48,235 25% 17,629 16%
Customer C - Jack-up Operations 26,205 12% - - - -
</TABLE>
* Less than 10%
40
<PAGE> 43
MARINE DRILLING COMPANIES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (CONTINUED)
As is typical in the industry, the Company does business with a
relatively small number of customers at any given time. The loss of any one of
such customers could, at least on a short-term basis, have a material adverse
effect on the Company's profitability. Management believes, however, that at
current levels of drilling activity, the Company would have alternative
customers for its services if it lost any single customer and that the loss of
any one customer would not have a material adverse effect on the Company on a
long-term basis.
(12) RELATED PARTY TRANSACTIONS
In August 1997 Marine Drilling Companies (Norway) ASA acquired 100% of
Norwegian Drilling Technology AS ("NDT") a Norwegian corporation. Idar Iversen,
former President and Chief Executive Officer of Marine Drilling Companies
(Norway) ASA owned 50% of NDT at the time of the purchase. Mr. Iversen no longer
has any interests in NDT and is no longer employed by the Company.
(13) UNAUDITED QUARTERLY FINANCIAL DATA
A summary of unaudited quarterly consolidated financial information for
1998 and 1997 is as follows (in
thousands):
<TABLE>
<CAPTION>
FIRST SECOND THIRD FOURTH
1998 QUARTER QUARTER QUARTER QUARTER
-------------------------------------------- ------------- ------------- ------------- ------------
<S> <C> <C> <C> <C>
Revenues $ 57,464 $ 64,141 $ 63,452 $ 42,958
Operating income 25,478 30,864 26,199 10,830
Income before income taxes 26,199 31,469 26,809 11,064
Income tax expense 9,441 11,360 9,884 4,035
Net income 16,758 20,109 16,925 7,029
Basic earnings per share (1) $ 0.32 $ 0.38 $ 0.32 $ 0.13
Diluted earnings per share (1) $ 0.32 $ 0.38 $ 0.32 $ 0.13
Basic average common shares 52,987 52,240 52,289 52,334
Diluted average common shares 52,608 52,932 52,623 52,542
FIRST SECOND THIRD FOURTH
1997 QUARTER QUARTER QUARTER QUARTER
-------------------------------------------- ------------- ------------- ------------- ------------
Revenues $ 36,750 $ 44,486 $ 51,198 $ 57,823
Operating income 14,912 19,875 24,852 27,969
Income before income taxes 15,659 20,520 25,206 28,451
Income tax expense 5,481 7,182 8,918 9,875
Net income 10,178 13,338 16,288 18,576
Basic earnings per share (1) $ 0.20 $ 0.26 $ 0.32 $ 0.36
Diluted earnings per share (1) $ 0.19 $ 0.25 $ 0.31 $ 0.35
Basic average common shares 51,330 51,408 51,651 51,884
Diluted average common shares 52,494 52,604 52,601 52,856
- ------------------------------------
</TABLE>
(1) Quarterly net income per common share may not total to annual results due
to rounding.
41
<PAGE> 44
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
Not applicable.
PART III
The information called for by Part III, Items 10 through 13, of Form
10-K is incorporated by reference from the Registrant's Proxy Statements
relating to its annual meeting of Shareholders to be held May 13, 1999, which
will be filed by the Registrant with the Securities and Exchange Commission no
later than 120 days after the close of the fiscal year. Also reference is made
to the information contained under the captioned "Executive Officers of
Registrant" contained in Part I hereof.
PART IV
ITEM 14. EXHIBITS AND REPORTS ON FORM 8-K
(a) The following documents are included in Part II, Item 8:
(1) Consolidated Financial Statements
<TABLE>
<CAPTION>
Page
-----
<S> <C>
Independent Auditors' Report.................................................. 24
Consolidated Balance Sheets at December 31, 1998 and 1997..................... 25
Consolidated Statements of Operations for each of the years
in the three-year period ended December 31, 1998.......................... 26
Consolidated Statements of Shareholders' Equity for each of
the years in the three-year period ended December 31, 1998................ 27
Consolidated Statements of Cash Flows for each of the years
in the three-year period ended December 31, 1998.......................... 28
Notes to Consolidated Financial Statements.................................... 30
</TABLE>
All other schedules are omitted as the information is not required or is not
applicable.
42
<PAGE> 45
(2) Exhibits
Exhibit No.
-----------
3.1 Restated Articles of Incorporation of Marine Drilling
Companies, Inc. (incorporated by reference to Exhibit
28.17 to the Current Report on Form 8-K of the Registrant
dated October 30, 1992).
3.2 Amended and Restated Bylaws of Marine Drilling Companies,
Inc. (incorporated by reference to Exhibit 28.18 to the
Current Report on Form 8-K of the Registrant dated October
30, 1992).
++ 10.1 Employment Agreement between Marine Drilling
Companies, Inc. and Jan Rask dated June 18, 1996
(incorporated by reference to Exhibit 10.1 on Form 10-Q
for quarter ended June 30, 1996).
++* 10.2 Severance Agreement between Marine Drilling
Companies, Inc. and George G. Gentry, III dated November
15, 1998.
++ 10.3 Severance Agreement between Marine Drilling Companies,
Inc. and H. Larry Adkins dated July 18, 1996 (incorporated
by reference to Exhibit 10.3 on Form 10-Q for quarter
ended September 30, 1996).
++ 10.6 Marine Drilling Companies, Inc. 1995 Non-Employee
Directors' Plan (incorporated by reference to Annex A of
the Company's Proxy Statement dated July 17, 1995).
++ 10.7 Employment Agreement between Marine Drilling Companies,
Inc. and T. Scott O'Keefe dated January 12, 1998
(incorporated by reference to Exhibit 10.7 on Form 10-K
for year ended December 31,1997).
++ 10.9 Severance Agreement between Marine Drilling Companies,
Inc. and V. G. Bounds dated April 8, 1998 (incorporated by
reference to Exhibit 10.9 on Form 10-Q for quarter ended
March 1, 1998).
++ 10.10 Severance Agreement between Marine Drilling Companies,
Inc. and Dale W. Wilhelm, dated May 1, 1998 (incorporated
by reference to Exhibit 10.10 on Form 10-Q for quarter
ended March 31, 1998).
10.11 Amended and Restated Credit Agreement dated August 12,
1998 among Marine Drilling Companies and ABN AMRO Bank
N.V., Christiania Bank Og Kreditkasse, Credit Agricole
Indosuez, Bankers Trust Company, Skandinaviska Enskilda
Banken AB (Publ.), Bank Austria, Bank of Nova Scotia,
Banque Nationale Paris, Natexis Banque BFCE, and
Nederlandse Scheepshypotheekbank N.V. (incorporated by
reference to Exit 10.11 on Form 10-Q for the quarter ended
September 30, 1998.
++ 10.18 The Marine Drilling 1992 Long-Term Incentive Plan
(incorporated by reference to Exhibit 10.26 of the
Company's Registration Statement No. 33-52470 on Form
S-1).
++ 10.25 Marine Drilling Companies, Inc. Amended and Restated
Executive Deferred Compensation Plan effective
July 1, 1996 (incorporated by reference to Exhibit 10.25
on Form 10-K for the year ended December 31, 1996).
10.26 Marine Drilling Companies, Inc. Shareholders Rights
Agreement (incorporated by reference to Exhibits 1 - 5 to
the Current Report on Form 8-K of the Registrant dated
November 15, 1996).
* 21.1 Subsidiaries of the Registrant.
* 23.1 Consent of KPMG LLP.
* 27 Financial Data Schedule.
* Filed herewith.
++ Management contract or compensation plan or arrangement
required to be filed as an exhibit to this report.
- -------------
(b) Reports on Form 8-K:
No reports were filed on Form 8-K during the fourth quarter of 1998.
43
<PAGE> 46
SIGNATURES
PURSUANT TO THE REQUIREMENTS OF SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934, THE REGISTRANT HAS DULY CAUSED THIS REPORT TO BE SIGNED ON
ITS BEHALF BY THE UNDERSIGNED; THEREUNTO DULY AUTHORIZED, IN THE CITY OF SUGAR
LAND, STATE OF TEXAS, ON MARCH 26, 1999.
MARINE DRILLING COMPANIES, INC.
By /s/ JAN RASK
------------------------------
Jan Rask
President
PURSUANT TO THE REQUIREMENT OF THE SECURITIES EXCHANGE ACT OF 1934,
THIS REPORT HAS BEEN SIGNED BELOW BY THE FOLLOWING PERSONS ON BEHALF OF THE
REGISTRANT AND IN THE CAPACITIES AND ON THE DATE INDICATED:
<TABLE>
<CAPTION>
SIGNATURE TITLE DATE
<S> <C> <C>
/s/ ROBERT L. BARBANELL Chairman of the Board March 26, 1999
- ----------------------------------------
Robert L. Barbanell
/s/ JAN RASK President Chief Executive Officer March 26, 1999
- ----------------------------------------
Jan Rask And Director
/s/ T. SCOTT O'KEEFE Senior Vice President March 26, 1999
- ----------------------------------------
T. Scott O'Keefe Chief Financial Officer
(Principal Financial Officer)
/s/ DALE W. WILHELM Vice President and Controller March 26, 1999
- ----------------------------------------
Dale W. Wilhelm (Principal Accounting Officer)
/s/ ROBERT L. BARBANELL Director March 26, 1999
- ----------------------------------------
Robert L. Barbanell
/s/ DAVID A. B. BROWN Director March 26, 1999
- ----------------------------------------
David A. B. Brown
/s/ HOWARD L. BULL Director March 26, 1999
- ----------------------------------------
Howard L. Bull
/s/ J. C. BURTON Director March 26, 1999
- ----------------------------------------
J. C. Burton
/s/ DAVID B. ROBSON Director March 26, 1999
- ----------------------------------------
David B. Robson
/s/ ROBERT C. THOMAS Director March 26, 1999
- ----------------------------------------
Robert C. Thomas
</TABLE>
44
<PAGE> 47
INDEX TO EXHIBITS
<TABLE>
<CAPTION>
EXHIBIT
NUMBER Description
------- ---------------------------
<S> <C>
10.2 Severance Agreement between Marine Drilling
Companies, Inc. and George H. Gentry, III
dated November 15, 1998.
21.1 Subsidiaries of the Registrant.
23.1 Consent of KPMG LLP.
27 Financial Data Schedule
</TABLE>
<PAGE> 1
EXHIBIT 10.2
SEVERANCE AGREEMENT
AGREEMENT between MARINE DRILLING COMPANIES, INC., a Texas corporation
(the "Company"), and GEORGE H. GENTRY, III ("Executive"),
W I T N E S S E T H :
WHEREAS, the Company desires to attract and retain certain key employee
personnel and, accordingly, the Board of Directors of the Company (the "Board")
has approved the Company entering into a severance agreement with Executive in
order to encourage his continued service to the Company; and
WHEREAS, Executive is prepared to commit such services in return for
specific arrangements with respect to severance compensation and other
benefits;
NOW, THEREFORE, in consideration of the foregoing and for other good and
valuable consideration, the Company and Executive agree as follows:
1. Definitions.
(a) "Annual Compensation" shall mean an amount equal to the greater
of:
(i) Executive's annual base salary at the annual rate in effect
at the date of his Involuntary Termination; or
(ii) Executive's annual base salary at the annual rate in effect
immediately prior to a Change-in-Control if Executive's employment shall
be subject to a Change-in-Control Involuntary Termination.
(b) "Change-in-Control" shall have the meaning ascribed to such term
in Section 9(b) of The Marine Drilling 1992 Long-Term Incentive Plan (the
"Incentive Plan").
(c) "Change-in-Control Involuntary Termination" shall mean any
termination of Executive's employment with the Company which:
(i) results from a resignation by Executive within 12 months
after the date upon which a Change-in-Control occurs if such resignation
occurs within 30 days after Executive receives notice from the Company
that Executive will be subject to a Material Change in Employment Terms;
or
(ii) results from a termination by the Company within 12 months
after the date upon which a Change-in-Control occurs;
<PAGE> 2
provided, however, the term "Change-in-Control Involuntary Termination" shall
not include a Termination for Cause or any termination as a result of death,
Disability, or Retirement.
(d) "Compensation Committee" shall mean the Compensation Committee of
the Board.
(e) "Disability" shall mean that, as a result of Executive's incapacity
due to physical or mental illness, he shall have been absent from the full-time
performance of his duties for at least 90 consecutive days or for a period of
120 days during any 12-month period and he shall not have returned to full-time
performance of his duties within 30 days after written notice of termination is
given to Executive by the Company (provided, however, that such notice may not
be given prior to 30 days before the expiration of either such period).
(f) "Involuntary Termination" shall mean any Non-Change-in-Control
Termination or any Change-in-Control Involuntary Termination.
(g) "Material Change in Compensation" shall mean any one or more of the
following:
(i) a reduction in Executive's annual base salary from that
provided to him immediately prior to the effective date of this
Agreement; or
(ii) a significant diminution in Executive's eligibility to
participate in bonus, stock option, incentive award and other
compensation plans under which Executive is participating immediately
prior to the effective date of this Agreement.
(h) "Material Change in Employment Terms" shall mean any one or more of
the following:
(i) a material diminution in the nature or scope of Executive's
authorities, powers, functions or duties from those applicable to him
immediately prior to the date on which a Change-in-Control occurs;
(ii) a reduction in Executive's annual base salary from that
provided to him immediately prior to the date on which a
Change-in-Control occurs;
(iii) a significant diminution in Executive's eligibility to
participate in bonus, stock option, incentive award and other
compensation plans under which Executive is participating immediately
prior to the date on which a Change-in-Control occurs; or
(iv) a change in the location of Executive's principal place of
employment by the Company by more than 50 miles from the location where
he was principally employed immediately prior to the date on which a
Change-in-Control occurs.
-2-
<PAGE> 3
(i) "Non-Change-in-Control Involuntary Termination" shall mean any
termination of Executive's employment with the Company which:
(i) results from a resignation by Executive if but only if such
resignation occurs within 30 days after Executive receives notice from
the Company that (A) Executive's principal place of employment will be
moved by more than 50 miles from the location where he was principally
employed immediately prior to the date of such notice or (B) Executive
will be subject to a Material Change in Compensation; or
(ii) results from a termination by the Company;
provided, however, the term "Non-Change-in-Control Involuntary Termination"
shall not include a Termination for Cause, a Change-in-Control Involuntary
Termination or any termination as a result of death, Disability, or Retirement.
(j) "Retirement" shall mean termination of Executive's employment for
any reason on or after the date Executive reaches age sixty-five.
(k) "Severance Amount" shall mean an amount equal to Executive's Annual
Compensation.
(l) "Severance Period" shall mean the period commencing on the date of
an Involuntary Termination and continuing for 12 months.
(m) "Termination for Cause" shall mean termination of Executive's
employment by the Company for any of the following reasons:
(i) Executive has engaged in gross negligence or willful misconduct
in the performance of the duties required of him;
(ii) Executive has been convicted of a felony or a misdemeanor
involving moral turpitude;
(iii) Executive has willfully refused without proper legal reason
to perform the duties and responsibilities required of him;
(iv) Executive has materially breached any material corporate
policy or code of conduct established by the Company; or
(v) Executive has willfully engaged in conduct that he knows or
should know is materially injurious to the Company or any of its
affiliates.
2. Services. Executive agrees that he will render services to the
Company (as well as any subsidiary thereof or successor thereto) during the
period of his employment to the best of
-3-
<PAGE> 4
his ability and in a prudent and businesslike manner and that he will devote
substantially the same time, efforts and dedication to his duties as heretofore
devoted.
3. Termination. Subject to the provisions of Paragraph 5(i) hereof, if
Executive's employment by the Company or any subsidiary thereof or successor
thereto shall be subject to an Involuntary Termination, then the Company will,
as additional compensation for services rendered to the Company (including its
subsidiaries), pay to Executive the following amounts (subject to any applicable
payroll or other taxes required to be withheld and any employee benefit
premiums) and take the following actions:
(a) Pay Executive a lump sum cash payment in an amount equal to the
Severance Amount on or before the tenth day after the last day of Executive's
employment with the Company; provided, however, if such Involuntary Termination
is a Change-in-Control Involuntary Termination, then such lump sum cash payment
shall be in an amount equal to twice the Severance Amount.
(b) Immediately cause Executive and those of his dependents
(including his spouse) who were covered under the Company's medical and dental
benefit plans on the day prior to Executive's Involuntary Termination to
continue to be covered under such plans throughout the Severance Period, without
any cost to Executive; provided, however, that (i) such coverage shall terminate
if and to the extent Executive becomes eligible to receive medical and dental
coverage from a subsequent employer (and any such eligibility shall be promptly
reported to the Company by Executive) and (ii) if Executive (and/or his spouse)
would have been entitled to retiree medical and/or dental coverage under the
Company's plans had he voluntarily retired on the date of such Involuntary
Termination, then such coverages shall be continued as provided under such
plans.
(c) Immediately cause any and all outstanding options to purchase
common stock of the Company held by Executive, which options were granted prior
to December 31, 1995, to become immediately exercisable in full and to remain
exercisable during the period of three months following such termination (or
such greater period as the Committee (as such term is defined in the Incentive
Plan) may determine), or by Executive's estate (or the person who acquires such
options by will or the laws of descent and distribution or otherwise by reason
of the death of Executive) during a period of one year following Executive's
death if Executive dies during such three-month period (or such greater period
as the Committee may determine), but in no event shall any such option be
exercisable after the tenth anniversary of the grant of such option.
4. Parachute Payment Limitation. Notwithstanding anything to the
contrary in this Agreement, the amount of any benefits provided by this
Agreement shall be reduced or eliminated to the extent necessary so that no
payment made under this Agreement will subject Executive to an excise tax, as a
result of the Golden Parachute payment provisions contained in Sections 280G and
4999 of the Internal Revenue Code of 1986, as amended (ignoring, for purposes of
such excise tax calculation, payments under other agreements which will be made
after the payment to be made pursuant to this Agreement and which are subject to
a provision
-4-
<PAGE> 5
similar to this paragraph). Notwithstanding the foregoing, if payments which are
not made as a result of the preceding sentence ("Cutback Payment"), when
combined with payments under other agreements sponsored by the Company which
have not been paid as a result of a provision similar to this paragraph ("Prior
Cutback Payments"), would, if paid, result in Executive being in a better net
after-tax position (taking into account any applicable excise tax under Section
4999 of the Internal Revenue Code of 1986, as amended, and any income tax
applicable to payments made under this Agreement or under such other agreements)
than he would have been had such reduction or elimination not been made pursuant
to the preceding sentence and provisions similar to this paragraph in other
agreements, then the Cutback Payment shall then be paid notwithstanding the
preceding sentence and all Prior Cutback Payments shall also then be paid
notwithstanding any provisions similar to this paragraph applicable to such
Prior Cutback Payments. Prior to the date any payment is to be made to Executive
pursuant to this Agreement (without regard to this paragraph), the Company shall
provide Executive with its calculations relevant to this paragraph and such
supporting materials as are reasonably necessary for Executive to evaluate the
Company's calculations. If Executive objects to the Company's calculations, the
Company shall pay Executive such portion of the Cutback Payment and Prior
Cutback Payments (in each case, up to 100% thereof) as Executive determines is
necessary to comply with the intent of this paragraph.
5. General.
(a) Term. The effective date of this Agreement is November 15, 1998, and
this Agreement shall have an initial term (the "Initial Term") of one year
beginning on such effective date. The term of this Agreement shall be extended
automatically for an additional successive one-year period as of the last day of
the Initial Term and as of the last day of each such successive one-year period
of time thereafter that this Agreement is in effect; provided, however, that if,
prior to 90 days before the last day of the Initial Term or any such successive
one-year term, the Compensation Committee (excluding any member of the
Compensation Committee who is covered by this Agreement or by a similar
agreement with the Company) shall give written notice to Executive that no such
automatic extension shall occur, then this Agreement shall terminate on the last
day of the Initial Term or such successive one-year term, as applicable, during
which such notice is given. Notwithstanding anything to the contrary contained
in this "sunset provision," it is agreed that if a Change-in-Control occurs
while this Agreement is in effect, then this Agreement shall not be subject to
termination under this "sunset provision," and shall remain in force for a
period of 12 months after such Change-in-Control, and if within said 12 months
the contingency factors occur which would entitle Executive to the benefits as
provided herein, this Agreement shall remain in effect in accordance with its
terms. If, within such 12 months after a Change-in-Control, the contingency
factors that would entitle Executive to said benefits do not occur, thereupon
this "sunset provision" shall again be applicable with the 90-day time period
for Compensation Committee action to thereafter commence 90 days prior to the
first anniversary of such Change-in-Control and 90 days prior to each one-year
anniversary date thereafter.
(b) Indemnification. If Executive shall obtain any money judgment or
otherwise prevail with respect to any litigation brought by Executive or the
Company to enforce
-5-
<PAGE> 6
or interpret any provision contained herein, the Company, to the fullest extent
permitted by applicable law, hereby indemnifies Executive for his reasonable
attorneys' fees and disbursements incurred in such litigation.
(c) Payment Obligations Absolute. The Company's obligation to pay (or
cause one of its subsidiaries to pay) Executive the amounts and to make the
arrangements provided herein shall be absolute and unconditional and shall not
be affected by any circumstances, including, without limitation, any set-off,
counterclaim, recoupment, defense or other right which the Company (including
its subsidiaries) may have against him or anyone else. All amounts payable by
the Company (including its subsidiaries hereunder) shall be paid without notice
or demand. Executive shall not be obligated to seek other employment in
mitigation of the amounts payable or arrangements made under any provision of
this Agreement, and, except as provided in Paragraphs 3(b) hereof, the obtaining
of any such other employment shall in no event effect any reduction of the
Company's obligations to make (or cause to be made) the payments and
arrangements required to be made under this Agreement.
(d) Successors. This Agreement shall be binding upon and inure to the
benefit of the Company and any successor of the Company, by merger or otherwise.
This Agreement shall also be binding upon and inure to the benefit of Executive
and his estate. If Executive shall die prior to full payment of amounts due
pursuant to this Agreement, such amounts shall be payable pursuant to the terms
of this Agreement to his estate.
(e) Severability. Any provision in this Agreement which is prohibited or
unenforceable in any jurisdiction by reason of applicable law shall, as to such
jurisdiction, be ineffective only to the extent of such prohibition or
unenforceability without invalidating or affecting the remaining provisions
hereof, and any such prohibition or unenforceability in any jurisdiction shall
not invalidate or render unenforceable such provision in any other jurisdiction.
(f) Non-Alienation. Executive shall not have any right to pledge,
hypothecate, anticipate or assign this Agreement or the rights hereunder, except
by will or the laws of descent and distribution.
(g) Notices. Any notices or other communications provided for in this
Agreement shall be sufficient if in writing. In the case of Executive, such
notices or communications shall be effectively delivered if hand delivered to
Executive at his principal place of employment or if sent by registered or
certified mail to Executive at the last address he has filed with the Company.
In the case of the Company, such notices or communications shall be effectively
delivered if sent by registered or certified mail to the Company at its
principal executive offices.
(h) Controlling Law. This Agreement shall be governed by, and construed
in accordance with, the laws of the State of Texas.
(i) Release. As a condition to the receipt of any benefit under
Paragraph 3 hereof, Executive shall first execute a release, in the form
established by the Company, releasing
+ -6-
<PAGE> 7
the Company, its shareholders, partners, officers, directors, employees and
agents from any and all claims and from any and all causes of action of any kind
or character, including but not limited to all claims or causes of action
arising out of Executive's employment with the Company or the termination of
such employment.
(j) Full Settlement. If Executive is entitled to and receives the
benefits provided hereunder, performance of the obligations of the Company
hereunder will constitute full settlement of all claims that Executive might
otherwise assert against the Company on account of his termination of
employment. Executive hereby acknowledges that the Company has heretofore
rescinded and terminated the Company's Executive Severance Policy, as amended
from time to time, which policy was originally adopted on January 1, 1994, and
Executive hereby waives any and all rights Executive may have under such policy.
(k) Unfunded Obligation. The obligation to pay amounts under this
Agreement is an unfunded obligation of the Company, and no such obligation shall
create a trust or be deemed to be secured by any pledge or encumbrance on any
property of the Company (including its subsidiaries).
(l) Not a Contract of Employment. This Agreement shall not be deemed to
constitute a contract of employment, nor shall any provision hereof affect (a)
the right of the Company (or its subsidiaries) to discharge Executive at will or
(b) the terms and conditions of any other agreement between the Company and
Executive except as provided herein.
(m) Number and Gender. Wherever appropriate herein, words used in the
singular shall include the plural and the plural shall include the singular. The
masculine gender where appearing herein shall be deemed to include the feminine
gender.
-7-
<PAGE> 8
IN WITNESS WHEREOF, the parties hereto have executed this Agreement as
of the 15th day of November, 1998.
"EXECUTIVE"
/s/ GEORGE H. GENTRY, III
------------------------------------
George H. Gentry, III
"COMPANY"
MARINE DRILLING COMPANIES, INC.
By: /s/ JAN RASK
---------------------------------
Name: Jan Rask
Title: Chief Executive Officer
-8-
<PAGE> 1
EXHIBIT 21.1
MARINE DRILLING COMPANIES, INC.
SUBSIDIARIES AND PARTNERSHIPS
DECEMBER 31, 1998
<TABLE>
<CAPTION>
Place of
Incorporation Ownership
Subsidiary/Partnership or Domicile Owner Percentage
- ------------------------------------------------- ---------------- ---------------------------------------------------------------
<S> <C> <C> <C>
Marine Drilling Management Company Dover, Marine Drilling Companies, Inc. 100%
Delaware
USA
Marine Drilling International, Inc. Dover, Marine Drilling Management Company 100%
Delaware
USA
Marine 300 Series, Inc. Dover, Marine Drilling Companies, Inc. 100%
Delaware
USA
</TABLE>
<PAGE> 1
EXHIBIT 23.1
CONSENT OF INDEPENDENT AUDITORS
The Board of Directors and Shareholders
Marine Drilling Companies, Inc.:
We consent to incorporation by reference of our report dated January 26, 1999,
relating to the consolidated balance sheets of Marine Drilling Companies, Inc.
and subsidiaries as of December 31, 1998, and 1997, and the related
consolidated statements of operations, shareholders' equity, and cash flows for
each of the years in the three-year period ended December 31, 1998, which
report appears in the December 31, 1998 annual report on Form 10-K of Marine
Drilling Companies, Inc., in the following registration statements of Marine
Drilling Companies, Inc.: (i) No. 33-56920 on Form S-8 dated January 11, 1993,
(ii) No. 33-61901 on Form S-8 dated August 17, 1995, (iii) No. 333-6995 on Form
S-4 dated June 27, 1996 and amended July 11, 1996, (iv) No. 333-6997 on Form
S-3 dated June 27, 1996, amended July 11, 1996 and supplement dated November
22, 1996., and (v) No. 333-56379 on Form S-3 dated June 9, 1998.
KPMG LLP
Houston, Texas
March 29, 1999
<TABLE> <S> <C>
<ARTICLE> 5
<MULTIPLIER> 1,000
<S> <C> <C> <C>
<PERIOD-TYPE> YEAR YEAR YEAR
<FISCAL-YEAR-END> DEC-31-1998 DEC-31-1997 DEC-31-1996
<PERIOD-END> DEC-31-1998 DEC-31-1997 DEC-31-1996
<CASH> 12,576 15,619 71,961
<SECURITIES> 0 0 9,990
<RECEIVABLES> 23,176 46,680 21,378
<ALLOWANCES> 0 0 0
<INVENTORY> 579 456 897
<CURRENT-ASSETS> 39,621 72,347 105,687
<PP&E> 500,510 310,122 182,200
<DEPRECIATION> 68,881 49,635 33,463
<TOTAL-ASSETS> 475,684 334,182 254,947
<CURRENT-LIABILITIES> 32,922 16,875 9,016
<BONDS> 0 0 0
0 0 0
0 0 0
<COMMON> 524 519 513
<OTHER-SE> 361,064 295,223 221,220
<TOTAL-LIABILITY-AND-EQUITY> 475,684 334,182 254,947
<SALES> 228,015 190,257 110,329
<TOTAL-REVENUES> 228,015 190,257 110,329
<CGS> 102,166 77,847 59,770
<TOTAL-COSTS> 102,166 77,847 59,770
<OTHER-EXPENSES> 20,191 16,995 11,576
<LOSS-PROVISION> 0 0 0
<INTEREST-EXPENSE> 481 575 895
<INCOME-PRETAX> 95,541 89,836 32,256
<INCOME-TAX> 34,720 31,456 11,586
<INCOME-CONTINUING> 60,821 58,380 20,670
<DISCONTINUED> 0 0 0
<EXTRAORDINARY> 0 0 0
<CHANGES> 0 0 0
<NET-INCOME> 60,821 58,380 20,670
<EPS-PRIMARY> 1.16 1.13 0.46
<EPS-DILUTED> 1.15 1.11 0.45
</TABLE>
