UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
----------------------
FORM 10-K
(MARK ONE)
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED DECEMBER 31, 2002
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
COMMISSION FILE NUMBER 000-32855
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TORCH OFFSHORE, INC.
(Exact Name of Registrant as Specified in its Charter)
DELAWARE 74-2982117
(State or Other Jurisdiction of (I.R.S. Employer
Incorporation or Organization) Identification No.)
401 WHITNEY AVENUE, SUITE 400
GRETNA, LOUISIANA 70056-2596
(Address of Principal Executive Offices) (Zip Code)
Registrant's Telephone Number, Including Area Code: (504) 367-7030
Securities Registered Pursuant to Section 12(b) of the Act: NONE
Securities Registered Pursuant to Section 12(g) of the Act:
COMMON STOCK, $0.01 PAR VALUE PER SHARE
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities 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. [ ]
Indicate by check mark whether the registrant is an accelerated filer
as defined in Rule 12b-2 of the Securities Exchange Act of 1934. Yes [ ] No [X]
The aggregate market value of the voting stock held by non-affiliates
of the registrant as of March 25, 2003 was approximately $21.9 million. The
number of shares of the registrant's common stock, $0.01 par value per share,
outstanding as of March 25, 2003 was 12,635,030.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant's Proxy Statement for the registrant's 2003
Annual Meeting of Stockholders to be filed pursuant to Regulation 14A are
incorporated by reference into Part III of this Form 10-K.
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TORCH OFFSHORE, INC.
ANNUAL REPORT ON FORM 10-K
FOR THE YEAR ENDED DECEMBER 31, 2002
TABLE OF CONTENTS
PAGE
----
PART I
Item 1. Business ..................................................................................... 3
Item 2. Properties ................................................................................... 19
Item 3. Legal Proceedings ............................................................................ 20
Item 4. Submission of Matters to a Vote of Security Holders .......................................... 21
PART II
Item 5. Market for Registrant's Common Equity and Related Stockholder Matters ........................ 21
Item 6. Selected Financial Data ...................................................................... 21
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations ........ 23
Item 7a. Quantitative and Qualitative Disclosure About Market Risk .................................... 33
Item 8. Financial Statements and Supplementary Data .................................................. 34
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure ......... 53
PART III
Item 10. Directors and Executive Officers of the Registrant ........................................... 53
Item 11. Executive Compensation ....................................................................... 53
Item 12. Security Ownership of Certain Beneficial Owners and Management ............................... 54
Item 13. Certain Relationships and Related Transactions ............................................... 54
Item 14. Controls and Procedures ...................................................................... 54
PART IV
Item 15. Exhibits, Financial Statement Schedules and Reports on Form 8-K .............................. 55
Signatures ................................................................................... 57
Certifications ............................................................................... 58
Glossary of Certain Industry Terms .......................................................... G-1
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PART I
FORWARD-LOOKING STATEMENTS
This Form 10-K includes certain statements that are "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. In some cases,
you can identify forward-looking statements by terminology such as "may,"
"will," "should," "could," "expects," "intends," "plans," "anticipates,"
"believes," "estimates," "predicts," "potential," "continue," "projects," or the
negative of these terms, or other comparable terminology. All statements other
than statements of historical facts included in this Form 10-K, including,
without limitation, statements under "Item 1. Business," "Item 2. Properties,"
and "Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations" relating to future events or our future financial
performance, including our business strategy, are forward-looking statements.
These forward-looking statements involve risks and uncertainties that are beyond
our control. Factors that may cause our company's or our industry's actual
results, levels of activity, performance or achievements to be materially
different from those expressed or implied by the forward-looking statements
include or relate to the following: general economic and business conditions and
industry trends; decisions about offshore developments made by oil and natural
gas companies; the highly competitive nature of our business; the availability
and terms of capital; operating risks normally incidental to offshore
exploration, development and production operation; and changes in existing
environmental regulatory matters. Additional risks and other factors include
those listed under "Item 1. Business - Risk Factors" and elsewhere in this Form
10-K.
Although we believe that the expectations reflected in the forward-looking
statements are reasonable, we cannot guarantee future results, levels of
activity, performance or achievements. These statements are based upon certain
assumptions and analyses made by our management in light of its experiences and
its perception of historical trends, current conditions, expected future
developments and other factors it believes are appropriate in the circumstances.
Many of these factors are beyond our ability to control or predict. We caution
investors not to place undue reliance on forward-looking statements. These
forward-looking statements speak only as of the date of this report and we
disclaim any obligation to update the forward-looking statements contained in
this report, whether as a result of receiving new information, the occurrence of
future events or otherwise.
ITEM 1. BUSINESS
GENERAL
As used herein, the terms "Company," "Torch Offshore," "we" and "us" refer to
Torch Offshore, Inc. and its subsidiaries, unless the context requires
otherwise. Certain terms relating to the industry are defined in "Glossary of
Certain Industry Terms," which begins on page G-1 of this Form 10-K.
Torch Offshore, Inc. and its subsidiaries provide subsea construction services
in connection with the infield development of offshore oil and natural gas
reservoirs. We are a leading service provider in our market niche of installing
small diameter flowlines and related infrastructure associated with the
development of offshore oil and natural gas reserves on the Continental Shelf of
the Gulf of Mexico (the "Shelf"). Our customers are major oil and natural gas
companies as well as independent oil and natural gas operators. The primary
services we provide include:
o installation of flowlines and related infrastructure;
o pipeline tie-ins and tie-backs;
o riser installation;
o pipeline surveys and installation engineering; and
o integrated construction support.
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Our vessels primarily install marine pipelines that transport oil and natural
gas to production platforms and subsea production systems. We also connect
production platforms to trunklines that transport oil and natural gas to shore.
In a typical offshore field, several development wells are drilled to produce
the field. The production from each of the wells is then transported through
relatively small diameter flowlines to a production platform where it is
aggregated and sometimes treated before being transported through a larger
trunkline to shore. The wells frequently are completed on the ocean floor with
production systems that need to be connected by umbilicals to the platform so
that power can be supplied to the subsea systems and communications and control
can be maintained. Umbilicals are control lines arranged in a bundle that can
include power cables and injection lines. We specialize in the installation and
connection of these smaller flowlines and umbilicals, including the simultaneous
laying and burying of flowlines and the laying of both flexible flowlines and
coiled tubing. Combining our dive support vessels and remotely operated vehicles
(ROV's) with our pipelay vessels allows us to install pipelines in a more
coordinated fashion than is typical in our industry.
Historically, we have focused on performing projects involving pipelines with
diameters of twelve inches or less in water depths of 200 feet or less on the
Shelf. Such pipelines are required to be buried below the sea floor. We provide
additional services in connection with the infield development of offshore oil
and natural gas fields, including inspection and maintenance services, pipeline
tie-ins and tie-backs, riser installation, pipeline surveys and installation
engineering and integrated construction support. These services support offshore
infrastructure construction projects involving pipelines, production platforms
and subsea production systems and are frequently performed in conjunction with
our pipelay or umbilical installations. Our vessels provide a mobile above-water
platform that functions as an operational base for divers in water depths up to
1,000 feet and for Rov's at all practical water depths. In water depths up to
1,000 feet, we typically use our own divers and dive support personnel because
we believe it provides greater control over project costs and improves the
quality of work performed. We own and operate two saturation diving systems and
provide support services for operations such as hook-up and structure
abandonment, including barge and logistic support, minimal steel fabrication,
call-out diving and the chartering of vessels.
In addition, we have recently expanded our operations, fleet capabilities and
management expertise to enable us to provide services in the deepwater market
analogous to the services we can provide on the Shelf. In those markets that we
will target, deepwater operations are generally considered as providing services
in water depths in excess of 1,000 feet. We have only done a limited amount of
deepwater subsea construction work to date, but we expect to further our
involvement in the deepwater in the near future with additional subsea
construction projects and pipelay work.
The following table sets forth our historical operating data for the periods
indicated:
YEARS ENDED DECEMBER 31,
2002 2001 2000 1999 1998
---------- ---------- ---------- ---------- ----------
Pipelay:(1)
Total mileage .............................. 227 190 194 117 137
Number of jobs ............................. 63 66 64 31 44
Water depth range (feet) ................... 12-600 10-305 9-310 8-275 15-235
Diameter range (inches) .................... 1-12 2-16 2-10 2-12 2-8
Diameter range (as % of revenues):
1"-3" .................................... 6% 3% 11% 12% 10%
4"-6" .................................... 58% 74% 72% 63% 78%
8"-10" ................................... 22% 17% 17% 22% 12%
12"+ ..................................... 14% 6% 0% 3% 0%
Average length per job (miles) .............. 3.6 2.9 3.0 3.8 3.1
Average revenue per mile .................... $ 256,300 $ 262,100 $ 207,800 $ 155,600 $ 236,482
Other:(2)
Number of jobs ............................. 13 15 8 21 29
Water depth range (feet) ................... 48-7,200 5-500 50-3,700 15-328 20-480
Average revenue per job .................... $ 755,500 $ 616,900 $ 737,400 $ 145,200 $ 235,345
----------
(1) Includes pipelines and umbilicals.
(2) Includes inspection and maintenance services, pipeline tie-ins and
tie-backs, riser installation, pipeline surveys, installation
engineering, and integrated construction support.
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Our business was started in 1978. Torch Offshore, Inc., a Delaware corporation,
was formed in January 2001 in connection with our initial public offering. Our
principal executive offices are located at 401 Whitney Avenue, Suite 400,
Gretna, Louisiana 70056-2596, and our telephone number at that address is (504)
367-7030. We make available free of charge through our website,
www.torchinc.com, our annual report on Form 10-K, quarterly reports on Form
10-Q, current reports on Form 8-K, and all amendments to those reports as soon
as reasonably practicable after such material is electronically filed with the
Securities and Exchange Commission. Information on our website is not a part of
this report.
INDUSTRY
General. The subsea construction industry installs and maintains platforms,
pipelines and subsea field development hardware for offshore oil and natural gas
producers. Demand for subsea construction services is driven primarily by:
o worldwide demand for oil and natural gas and oil and natural gas prices;
o discoveries of new reserves;
o the amount of capital spending associated with developing new oil and
natural gas fields;
o the need to maintain and repair existing offshore production facilities
during their economic life; and
o regulatory requirements to remove production facilities after depletion of
the fields.
The time required to drill an exploratory well and formulate a development plan
creates a time lag between the start of drilling activities and increased demand
for offshore construction services. The time that elapses between a successfully
drilled well and the development phase, in which we participate, varies
depending on the water depth of the field. Oil and natural gas fields located on
the Shelf may require from three to twelve months from drilling activities to
development. Deepwater fields typically require eighteen months to three years
from drilling activities to development.
In addition to the influence that oil and natural gas prices have on demand,
seasonality also plays a role in the timing of contracts we receive. A large
portion of the contracts for marine construction in the Gulf of Mexico are
awarded in the early to late summer and are usually performed before the adverse
weather conditions of the winter months commence, as many of the projects are
completed within a relatively short period of time. Therefore, the third and
fourth quarter earnings are usually influenced positively by these seasonality
factors.
Because of the higher absolute cost of production, construction and drilling
equipment, primarily major oil and natural gas companies and a few large
independents and state-owned oil and natural gas operators conduct exploration
and production activities in the deepwater market. In the Gulf of Mexico,
deepwater production of oil has been much more prolific than existing production
on the Shelf and this deepwater oil production typically requires heavily
insulated flowlines. The net effect has been that, despite the high absolute
costs of deepwater production, the costs per barrel produced have been
relatively modest.
Industry Spending. The amount of capital expended by oil and natural gas
companies fluctuates from year to year based upon unpredictable issues including
the overall volatility of oil and natural gas prices. The independent oil and
natural gas operators tend to demonstrate more sensitivity to the fluctuation of
commodity prices. However, the major oil and natural gas companies are less
affected by commodity price fluctuation.
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STRATEGY
We believe that we are well positioned to take advantage of activity in the Gulf
of Mexico and that our greatest long-term growth opportunities lie in the
natural extension of our niche services into the deepwater market. Our strategy,
therefore, is to continue to take advantage of opportunities on the Shelf while
expanding our niche services into the deepwater markets of the world, including
the Gulf of Mexico, Brazil and West Africa. We intend to execute our deepwater
expansion strategy by:
o focusing on projects involving small diameter infield flowlines and related
infrastructure where we have analogous expertise on the Shelf;
o providing cost effective services through an expanded fleet of specially
designed and equipped vessels; and
o leveraging our alliance and customer relationships.
Our expertise and experience in our market niche on the Shelf should provide us
with an advantage in the analogous deepwater market worldwide. Development
projects in deepwater require many of the same types of services we currently
provide on the Shelf. For example, deepwater production facilities such as
tension leg platforms, spars and floating production, storage and offloading
vessels all require the extensive use of small diameter pipelines and
umbilicals. These small diameter lines provide similar functions in deepwater
that they provide on the Shelf.
Shelf Market Compared to Deepwater Market. There are a number of characteristics
about the deepwater market that differentiate it from the Shelf market.
On the Shelf, wells are generally drilled using conventionally-moored
semisubmersible or jack-up drilling rigs. Fixed platforms can be installed using
conventionally-moored construction vessels. Afterwards, the pipeline and riser
infrastructure can be installed using conventionally-moored S-lay vessels and
four-point dive boats equipped with mixed gas or saturation diving equipment.
Collectively, these technologies are mature, and, while there have been
improvements, the basic processes have not fundamentally changed in the last 25
years.
In the deepwater market, exploration and development techniques are
significantly different. Deepwater drilling and construction vessels are larger
and more sophisticated than vessels that work on the Shelf and are often
equipped with dynamic positioning, or DP, systems that allow them to move or
hold position within tight tolerances without using conventional moorings. This
capability is an advantage for holding position and for umbilical and pipelay
installation operations. In addition, fixed structures are replaced by either
floating production systems or subsea facilities in deepwater.
Several different physical configurations have been used for floating production
systems. In the Gulf of Mexico, tension leg platforms, spars, and floating
production units have been used. In other deepwater regions of the world,
floating production, storage and offloading vessels have also been used. Each of
these systems requires subsea field development hardware, including mooring
equipment, wellheads, subsea trees, manifolds, infield flowlines, risers and
infield umbilicals. We intend to focus our deepwater expansion efforts generally
on the installation of this equipment and particularly on the installation of
infield flowlines and related infrastructure, where we have analogous expertise
operating on the Shelf.
We believe that we have an advantage in our market niche on the Shelf because of
the cost efficiencies derived from the design and capabilities of our vessels
and from our operating methodology, which takes advantage of our dive support
vessels and divers to complete riser and pipeline tie-ins without impeding the
progress of our pipelay barges. The vessels used to install trunklines are
larger and require larger crews than the vessels we operate, making it less cost
effective for
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them to compete with us for small diameter, infield installation services. We
believe that we can extend this advantage to deepwater markets by employing
vessels that are specially designed and equipped to provide our niche services
in the most efficient and cost effective manner. In 2000, we completed the
construction of a fully redundant, dynamically positioned (DP-2) pipelay/bury
barge (the Midnight Eagle) and chartered a new DP-2 subsea construction vessel
(the Midnight Arrow). In early 2002, we purchased a 520-foot vessel that we are
converting into a DP-2 offshore construction vessel with our patent-pending
pipelay system (the Midnight Express). The system will be installed during the
conversion of the Midnight Express and is designed to combine the advantages of
several systems already in use, such as the ability to lay limited lengths of
products at high laying rates from a reel, the ability to lay unlimited lengths
of rigid pipelines without the need to come back to dock to reload, the capacity
to spool pipelines from an on-board firing line, and the ability to J-lay
pipelines or other products in order to minimize top tension. The pipelay system
includes a storage reel made of two drums operated independently, each capable
of storing up to 600 Te (metric tons) of product depending on product diameter
and schedule and a stern-laying tilting tower (from 65 degrees to 90 degrees)
supporting, from top to bottom, two bend controllers, two straighteners, a 160
Te tensioner, two workstations, a hang-off clamp, a pipe monitoring system and a
product departure roller box. A six-station firing line will be installed on the
deck of the Midnight Express to fabricate pipeline stored on the reel. The
conversion of this vessel will make it a new generation, specially designed and
equipped deepwater pipelay and subsea construction vessel capable of operating
in water depths of up to 10,000 feet. Most recently, in March 2003, we purchased
a versatile cable-lay vessel which we will outfit to become a versatile
deepwater pipelay and subsea construction vessel named the Midnight Wrangler,
which will be capable of laying rigid pipe, flexible pipe, coiled tubing and
umbilicals and providing light construction, diving and ROV support. However,
there are factors that may impact our further expansion into the deepwater
including the need for capital and the acquisition of additional vessels that
are capable of working in the deepwater.
It has been our management's experience that major oil and natural gas companies
approach large development projects in deepwater regions by dividing them into
discrete functional work packets which are then bid and awarded to a series of
individual contractors who have been pre-qualified to perform a particular
function. Major oil and natural gas companies maintain a group of construction
experts on staff to divide up the work, to identify qualified contractors, and
to coordinate and supervise the work program using these multiple contractors.
This approach to contracting is frequently referred to as "best-in-class"
contracting.
It has been management's experience that the other major approach, termed "EPIC"
contracting (engineer, procure, install, and commission), is preferred by
independent oil and natural gas operators as well as by many foreign national
oil companies. In EPIC contracting, a large engineering firm undertakes to
deliver the completed project for a lump sum. That contractor then directly
performs those portions of the scope within its capabilities and subcontracts
out those where it does not have "in house" talent or capacity. The integration
functions are the responsibility of the EPIC contractor.
Because the major integrated oil companies are disproportionately present in
deepwater, we believe that best-in-class contracting will dominate the deepwater
portions of our business activity. We expect that we will be able to pre-qualify
and to bid directly to the major integrated oil companies without having to
provide other engineering/contracting services. At the same time, on the Shelf,
where independent oil and natural gas operators predominate, we can continue to
bid through the engineering firms who provide project management and other EPIC
services to these clients.
Many of our Shelf customers are also active in deepwater exploration and
development. We intend to leverage our customer relationships to obtain
deepwater projects. In addition to our deepwater expansion strategy, we intend
to maintain a flexible fleet in order to take advantage of periods of increased
activities on the Shelf. The design and capabilities of our existing vessels
allow us to be an efficient provider of pipeline installation and subsea
construction services on the Shelf. See "Management's Discussion and Analysis of
Financial Condition and Results of Operations - Outlook."
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OUR FLEET
We operate a diversified fleet of nine construction and service vessels. In
addition, we will be adding two vessels to our active fleet in the coming
months. In January 2002, we purchased the Smit Express, which has been renamed
the Midnight Express, and we are converting it into a DP-2 deepwater offshore
construction vessel with our patent-pending pipelay system. The vessel is
expected to enter our active fleet in early 2004. In December 2002, we purchased
the Wave Alert, renamed the Midnight Wrangler, which we took possession of in
March 2003. We will make various modifications to the Midnight Wrangler before
it enters our active fleet in the second quarter of 2003. The following table
summarizes the capabilities of the nine vessels in our current fleet and the
expected capabilities of the Midnight Express and Midnight Wrangler.
VESSEL CAPABILITIES
--------------------------- ----------------------------------------------------------------------------------------
Midnight Arrow............. Diverless subsea construction in water depths of up to 10,000 feet.
Midnight Brave............. Simultaneous lay and bury of pipe up to 20" in diameter in water depths up to 400 feet.
Midnight Carrier........... Subsea construction with surface supply or saturation diving.
Midnight Dancer............ Subsea construction with surface supply diving.
Midnight Eagle............. Simultaneous lay and bury of pipe up to 8" in diameter in water depths of up to 100 feet.
Sequential lay and bury of pipe up to 10" in diameter in water depths of up to 200 feet.
Also capable of saturation diving in depths up to 1,000 feet and ROV support and light
construction work in up to 10,000 feet.
Midnight Express........... Designed to lay pipe up to 12" in diameter for rigid pipelines or 15" in diameter for
flexible flowlines in water depths of up to 10,000 feet and to provide
diverless subsea construction support in water depths of up to 10,000 feet.
Midnight Fox............... Personnel transport and support vessel (fuel, water, crew change).
Midnight Rider............. Lay pipe of up to 36" in diameter in water depths of up to 30 feet. Vessel can lay up to
10" diameter pipe in water depths up to 600 feet and up to 12" diameter pipe in water
depths up to 300 feet.
Midnight Runner............ Simultaneous lay and bury of pipe up to 20" in diameter in state waters only.
Midnight Star.............. Subsea construction with surface supply or saturation diving.
Midnight Wrangler.......... Designed to lay rigid pipe, flexible pipe, coiled tubing and umbilicals, utilizing up to
four reels, and to provide light construction and ROV support in up to 10,000 feet.
MIDNIGHT ARROW - DP-2 SUBSEA CONSTRUCTION VESSEL
The Midnight Arrow was delivered to us in early 2000 on a five-year charter.
Under the charter, we have an exclusive option to purchase the vessel for $8.25
million or the ability to extend the charter for an additional two years. The
vessel has a DP-2 system, accommodations for 54 workers, ROV capabilities to
approximately 10,000 feet, a helideck and a 45-ton crane. The vessel is 197 feet
long and 44 feet wide.
MIDNIGHT BRAVE - PIPELAY/BURY BARGE
The Midnight Brave was purchased in 1987 and presently has a pipelay ramp, five
workstations, a stinger and a digitally controlled 50 Kips tensioner. The vessel
is 275 feet long and 70 feet wide and has accommodations for 80 workers. It is
controlled using a seven-point mooring system.
MIDNIGHT CARRIER -- DIVING SUPPORT VESSEL
The Midnight Carrier was a pipe carrier that we purchased in May 1998. We then
initiated a series of overhauls and upgrades to allow the vessel's use as a
large four-point diving support vessel. We added a 650-foot four-point mooring
system and additional accommodations in 2000. The vessel is 270 feet long and 58
feet wide and accommodates 36 workers.
MIDNIGHT DANCER--DIVING SUPPORT VESSEL
The Midnight Dancer was purchased in 1994 and presently has a 15-ton crane, a
10-ton crane, a four-point mooring system, an air diving system and
accommodations for 46 workers. The vessel is 195 feet long and 40 feet wide.
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MIDNIGHT EAGLE - DP-2 PIPELAY/BURY BARGE
The Midnight Eagle was purchased in 1997 and placed in service in 2000 after
adding a DP-2 system, a 20-foot hull mid- section, two 10-foot wide sponsons,
four diesel driven azimuthing thrusters, a mooring/abandonment and recovery
winch, accommodations for 57 workers, generators and ancillary equipment. A
conventional firing line consisting of four workstations for S-lay and a 1,000
foot saturation diving system were also added. The vessel is 190 feet long and
76 feet wide.
MIDNIGHT EXPRESS (SMIT EXPRESS) - DP-2 PIPELAY/SUBSEA CONSTRUCTION VESSEL
The Smit Express was a LASH (Lighter Aboard Ship) barge transporter. We
purchased the vessel for $9.75 million in January 2002 and plan to place the
vessel into service in early 2004 pending the completion of the conversion and
sea trials. The ship is 520 feet long overall with a breadth of 100 feet. The
conversion will equip the vessel with our patent-pending pipelay system, a DP-2
system, a 2,500 square meter weather deck that will increase the ship freeboard
to nearly 14 feet, a 12 megawatt (MW) diesel electric generating plant, stern
azimuthing Z-drives and bow thrusters, ship services for project requirements, a
300 Te pedestal crane, a 2 X 20 Te gantry crane, two abandonment and recovery
winches (capabilities to approximately 7,000 feet), a helideck for a S-61,
accommodations for 132 people and 5 offices.
MIDNIGHT FOX -- SUPPLY SUPPORT VESSEL
Built in 1998, the Midnight Fox is 130 feet long and 28 feet wide and is
equipped with a bow thruster. Its present primary role is as a personnel
transport and supply vessel supporting the rest of our fleet.
MIDNIGHT RIDER -- PIPELAY/BURY BARGE
Built in 1995, the vessel is equipped to lay and bury pipe using the
conventional S-lay method. Equipped with five workstations, the vessel features
a 50-foot stinger, a 110-foot stinger and a 50 Kips tensioner. The vessel is 260
feet long and 72 feet wide, has accommodations for up to 84 workers and is
controlled using an eight-point mooring system. The vessel is also capable of
working on spuds.
MIDNIGHT RUNNER -- PIPELAY/BURY BARGE
The Midnight Runner was built in 1983 and presently has two spuds, four
workstations, a 30 Kips tensioner, generators and ancillary equipment as well as
accommodations for 30 workers. The vessel is 160 feet long and 54 feet wide.
MIDNIGHT STAR -- DIVING SUPPORT VESSEL
The Midnight Star was purchased in 1997 and presently has a four-point mooring
system, a moonpool, a 650-foot saturation diving system, an air diving control
room, two 15-ton cranes and accommodations for 42 workers. The vessel is 197
feet long and 42 feet wide.
MIDNIGHT WRANGLER (WAVE ALERT) - DP-2 PIPELAY/SUBSEA CONSTRUCTION VESSEL
The Midnight Wrangler was purchased in 2002 as a deepwater pipelay and subsea
construction vessel. The vessel is 341 feet long and 64 feet wide and is
equipped with a DP-2 system, a 125-ton crane and accommodations for 55 workers.
The vessel is capable of laying rigid pipe, coiled tubing and umbilicals,
utilizing up to four reels and is capable of providing light construction,
diving and ROV support in water depths up to 10,000 feet.
In addition, we purchased the Midnight Gator, a supply barge, in September 2002
for $0.2 million. We are currently converting this piece of equipment into a
sand dredge and it will become available for use during the second quarter of
2003 for the purpose of jetting trenches for pipe burial in shallow waters. This
barge will not be included in our vessel utilization statistics.
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SAFETY & QUALITY ASSURANCE
In this performance-based industry, a successful safety program is both a
necessity and an invaluable asset. We maintain our Safety Management System to
reduce the possibility of accidents, mechanical occurrences and environmental
incidents. Our Health, Safety and Quality (HSQ) system, known as the "Top to
Bottom Safety Program," establishes guidelines to ensure compliance with all
applicable state and federal guidelines and provides training and safety
education through new employee orientations, which include first aid and CPR
training. In addition, prospective employees are required to submit to alcohol
and drug testing and all employees are subject to random testing. Our HSQ system
encompasses everything from simple rules, regulations and job safety analyses to
our more sophisticated peer assisted leadership and critical task
familiarization programs. Employees who do not adhere to our health, safety and
environmental guidelines could face immediate termination. We believe that the
HSQ system has been very effective in mitigating exposure and averting losses,
while helping to attract and retain customers and employees.
Industry associations, government regulators and our peers have recognized our
commitment to safety. In 2002, we earned compliance with the Department of
Transportation's Operator Qualification Program and, in June 2002, we were
awarded an International Safety Management (ISM) Certification by the American
Bureau of Shipping. In 2001 and 2000, we received special recognition by the
National Ocean Industries Association, the main trade organization for the
offshore services industry, for our "highly innovative and meritorious" Top to
Bottom Safety Program. We have also received commendations in 2001 from the
United States Coast Guard (the "Coast Guard"), the Minerals Management Service
(the "MMS") and the Marine Board of the National Research Council for our
significant safety achievements and continuing dedication to the safety of life
at sea. The Coast Guard has also honored us in 2000 with a Certificate of
Appreciation in recognition of notable services that have assisted greatly in
furthering the aims and functions of the Coast Guard and for outstanding and
innovative efforts in promoting offshore safety.
CUSTOMERS & CONTRACTING
Our customers are primarily major oil and natural gas companies and independent
oil and natural gas operators working in the Gulf of Mexico. During 2002 and
2001, we provided subsea construction services to 37 and 40 customers,
respectively. No individual customer accounted for more than 10% of our revenues
in the years ended December 31, 2002 and 2001. The level of construction
services required by any particular customer depends on the size of that
customer's capital expenditure budget devoted to development in any particular
year. Consequently, customers that account for a significant portion of contract
revenues in one fiscal year may represent an immaterial portion of contract
revenues in a subsequent fiscal year. With the exception of our alliance
agreement with Unocal Gulf Region USA (Unocal), our Shelf construction contracts
are typically of short duration, ranging from several days to two months.
We are normally awarded contracts from our customers by means of a highly
competitive bidding process whereby customers typically request bids a few
months prior to commencement of a project. We maintain a focused marketing
effort through market analysis and a dedicated sales force. We also maintain an
up-to-date database of market studies and statistical bidding analyses. We
further market ourselves to customers through localized efforts in Houston,
Texas and southeastern Louisiana. Most contracts are awarded on a fixed-price
basis, but we also perform work under "cost-plus" and "day rate" arrangements as
well as under hybrids of these arrangements. Under fixed-price contracts, we
provide specified services at a fixed price regardless of the amount of time and
materials actually required. As a result, we are responsible for all cost
overruns. Consequently, although fixed-price contracts may offer greater
potential profits, they also involve more risk than a cost-plus arrangement.
Under cost-plus arrangements, we receive a specified fee in excess of the direct
labor and material costs incurred. We are therefore protected against cost
overruns, but do not benefit directly from cost savings. For projects involving
day rate arrangements, our charges are based upon a rate schedule for the
services provided.
As we expand our operations into deepwater, the typical contract profile is
likely to change so that lead time, duration and our backlog of awarded but
unexecuted projects will increase. We also expect that a larger portion of our
contracts will be with major oil and natural gas companies as the deepwater
market continues to develop and as our fleet expands in 2003 and 2004.
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ALLIANCE AGREEMENT
Since May 1999, we have operated under an alliance agreement with Unocal under
which we provide at least 80% of the pipelay, burial and riser installation
projects for Unocal's operations in the Gulf of Mexico in water depths of up to
200 feet. Unocal conducts exploration, development and production activities on
the Shelf and deepwater areas of the Gulf of Mexico. Under the alliance
agreement, Unocal also considers us for projects, on a non-exclusive basis, in
water depths greater than 200 feet. The current alliance with Unocal expires in
December 2003.
COMPETITION
The offshore marine construction industry is highly competitive. While we
believe that availability, capability of equipment and personnel, the reputation
and experience of management and the efficiency and safety record of the
contractor are important factors in this industry, price is the primary factor
that determines which qualified contractor is awarded the contract. Contracts
for work on the Shelf are typically awarded on a competitive bid basis one to
three months prior to commencement of operations. Customers usually request bids
from all companies which they believe are technically qualified to perform the
project. In order to ensure that we have an opportunity to bid for these
projects, our marketing staff maintains contacts with offshore operators as well
as with the independent engineering firms that manage their construction
projects.
The lower degree of complexity and capital costs involved in Shelf marine
construction activities has allowed many entrants into that subsegment of the
market, most of whom are involved only in Shelf activities. There are relatively
few barriers to entry and older installation equipment is typical of many
companies. In addition, companies are differentiated by their capabilities to
perform "offshore" versus only "inshore," or in state waters projects. For
conventional offshore pipelay projects on the Shelf, we primarily compete with
Broussard Brothers, Inc., Chet Morrison Contractors, Inc., Global Industries,
Ltd. and Horizon Offshore, Inc., although Stolt Offshore S.A. and Saipem S.p.A.
also maintain a presence in this market.
For deepwater pipelay projects, the barriers to entry are numerous; the projects
are both engineering and capital intensive, with project durations measured in
years rather than months. The vessels are capital intensive and the supporting
technology is not widely distributed. In the deepwater, the major pipelay
competitors are foreign companies that include Technip-Coflexip, Stolt Offshore
S.A., Saipem S.p.A. (including Saibos), Allseas Group S.A., and Heerema Group.
Some of the domestic deepwater contractors include Halliburton-Subsea, McDermott
International, Inc., Global Industries, Ltd. and Cal Dive International, Inc. We
believe we are able to differentiate ourselves from this competition by having
an efficient fleet with a relatively low capital structure, which is a function
of maintaining focus on our specialty of infield flowlines and tie-backs.
BACKLOG
We do not consider our backlog amounts to be a reliable indicator of future
revenue because most of our Shelf-based contracts are awarded and performed
within a relatively short period of time. Thus, our backlog can fluctuate
significantly based on the level of drilling activity on the Shelf, the timing
of contract awards and the seasonal operating activity level throughout the
year. As deepwater projects become more prevalent in our product mix, we expect
to see an increased backlog because these projects have longer lead times than
their Shelf-based counterparts.
PATENTS
We have various pending patent applications for a deepwater pipeline laying
system designed by Lyle G. Stockstill, Chairman of the Board and Chief
Executive Officer. Although we believe this technology provides us with a
competitive advantage in the deepwater market, we do not regard patent
protection on such pipeline laying system as critical or essential to our
business. However, if patent protection is not granted on this technology, such
may impact our entry and operation in the deepwater market.
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EMPLOYEES
As of December 31, 2002, we had a total of 362 employees. Approximately 314 were
operating personnel and 48 were corporate, administrative and management
personnel. None of our employees belong to a union or are employed pursuant to
any collective bargaining agreement or any similar arrangement.
GOVERNMENT AND ENVIRONMENTAL REGULATION
General. Many aspects of our offshore marine construction industry are subject
to extensive governmental regulation by the Coast Guard, the National
Transportation Safety Board, the United States Customs Service (the "Customs
Service"), and the Occupational Safety and Health Administration, as well as by
private industry organizations such as the American Bureau of Shipping. The
Coast Guard and the National Transportation Safety Board set safety standards
and are authorized to investigate vessel accidents and recommend improved safety
standards, and the Customs Service is authorized to inspect vessels at will. The
Occupational Safety and Health Administration performs similar functions with
respect to both offshore and onshore facilities.
We are required by certain governmental and quasi-governmental agencies to
obtain various permits, licenses and certificates with respect to our
operations. We believe that we have obtained or will be able to obtain, when
required, all permits, licenses and certificates necessary to conduct our
business.
Maritime. Some of our employees are covered by provisions of the Jones Act, the
Death on the High Seas Act and general maritime law. Other non-maritime
employees are covered by the U.S. Longshoremen and Harbor Workers Compensation
Act. These laws typically operate to make liability limits established by state
workers' compensation laws inapplicable to these employees and to permit these
employees and their representatives to pursue actions against employers for job
related injuries in federal courts. Since we are not protected by the limits
imposed by state workers' compensation statutes, we may have greater exposure
for any claim made by such employees.
Because we engage in certain activities that may constitute "coastwise trade"
within the meaning of federal maritime regulations, we are also subject to
regulation by the United States Department of Transportation Maritime
Administration (MARAD), in addition to the Coast Guard and the Customs Service.
Under these regulations, only vessels owned by United States citizens which are
built and registered under the laws of the United States may engage in
"coastwise trade." Furthermore, the foregoing citizenship requirements must be
met in order for us to qualify for financing guaranteed by MARAD. To enjoy the
benefits of United States registry, United States coastwise trade and
MARAD-guaranteed financing, we must maintain United States citizenship as
defined in the Shipping Act of 1916 and the regulations thereunder. Under these
regulations, to maintain United States citizenship, our president or chief
executive officer, the chairman of our board of directors and a majority of a
quorum of our board of directors must be United States citizens. Further, at
least 75% of the ownership and voting power of our capital stock must be held by
United States citizens, as defined in the Shipping Act and the regulations
thereunder.
Environmental. Numerous federal, state and local laws and regulations relating
to protection of the environment affect our operations. The technical
requirements of these laws and regulations have become more complex and
stringent in recent years, and compliance is becoming increasingly difficult and
expensive. However, we do not believe that compliance with current environmental
laws and regulations is likely to have a material adverse affect on our business
or financial condition. Some environmental laws provide for strict liability for
remediation of spills and releases of hazardous substances, including oil, into
the environment, and some impose liability for damages to natural resources or
threats to public health and safety. Sanctions for noncompliance may include
revocation of permits, corrective action orders, administrative or civil
penalties, and criminal prosecution. It is possible that changes in the
environmental laws and enforcement policies under these laws, or claims for
damages to persons, property, natural resources or the environment, could result
in substantial costs and liabilities. Our insurance policies provide liability
coverage for sudden and accidental
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occurrences of pollution and/or cleanup and containment of the foregoing in
amounts that we believe are comparable to policy limits carried by others in the
offshore construction industry.
The Oil Pollution Act of 1990 (the "Oil Pollution Act") and regulations
promulgated thereunder 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, pipeline, or vessel, or the lessee or permittee of the area in which
an offshore facility is located. The Oil Pollution Act assigns maximum potential
liability to each responsible party for oil removal costs and a variety of
public and private damages. Vessels subject to the Oil Pollution Act, other than
tank vessels, are subject to liability limits of the greater of $2,000,000 or
$1,200 per gross ton. 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, the
liability limits likewise do not apply. Few defenses exist to the liability
imposed under the Oil Pollution Act. The Oil Pollution Act also imposes ongoing
requirements on a responsible party including preparation of an oil spill
contingency plan and proof of financial responsibility (to cover at least some
costs in a potential spill) for vessels in excess of 300 gross tons. We believe
that we currently have in place appropriate spill contingency plans and have
established adequate proof of financial responsibility for our vessels.
The Clean Water Act and analogous state laws provide strict controls on the
discharge of pollutants into the navigable waters of the United States and
impose liability for the costs of remediating releases of petroleum and other
hazardous substances. These laws provide for administrative, civil and criminal
penalties for any unauthorized discharge of oil and other hazardous substances
in reportable quantities and impose substantial potential liability for the
costs of removal, remediation and damages. Our vessels routinely transport small
amounts of hazardous substances and also carry diesel fuel for their own use.
All vessels we operate have vessel response plans to deal with potential spills
of hazardous substances including oil or its derivatives.
The Outer Continental Shelf Lands Act provides the federal government with broad
discretion in regulating the release of oil and natural gas in connection with
offshore oil and natural gas production. Because our operations rely on offshore
oil and natural gas exploration and production, if the government were to
exercise its authority under the Outer Continental Shelf Lands Act to restrict
the availability of offshore oil and natural gas leases, such an action could
have a material adverse effect on our financial condition.
The Comprehensive Environmental Response, Compensation and Liability Act
(CERCLA) and similar laws impose liability for releases of hazardous substances
into the environment. CERCLA currently exempts crude oil from the definition of
hazardous substances for purposes of the statute, but our operations may involve
the use or handling of other materials that may be classified as hazardous
substances. CERCLA assigns strict liability to each responsible party for all
response and remediation costs, as well as natural resource damages. Few
defenses exist to the liability imposed by CERCLA. We are not currently aware of
any events that, if brought to the attention of regulatory authorities, would
lead to the imposition of CERCLA liability.
Exploration and Production Industry. We depend on the demand for our services
from the oil and natural gas industry. Therefore, changes to laws, regulations,
taxes and policies relating to the oil and natural gas industry can also affect
our business. For example, the exploration and development of oil and natural
gas properties located on the Outer Continental Shelf of the United States is
regulated primarily by the MMS. The MMS has broad authority over such
operations. It must approve and grant permits in connection with drilling and
development plans submitted by oil and natural gas companies. Additionally, the
MMS has promulgated regulations requiring offshore production facilities to meet
stringent engineering and construction specifications restricting the flaring or
venting of natural gas, governing the plugging and abandonment of wells and
controlling the removal of production facilities. Further, under some
circumstances, the MMS has the authority to require the suspension or
termination of any operations on federal leases, and has proposed regulations
that would permit it to expel unsafe operators from offshore operations. The MMS
also has established rules governing the calculation of royalties and the
valuation of crude oil produced from federal offshore leases. The
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MMS has issued regulations regarding costs for natural gas transportation,
which are deductible for royalty valuation purposes when natural gas is sold off
lease. Delays in the approval of plans and issuance of permits by the MMS
because of staffing, economic, environmental or other reasons could adversely
affect our operations by limiting demand for our services. We cannot predict how
the MMS regulations may be amended in the future. However, any change in MMS
regulations that adversely affects offshore oil and natural gas operations has
the potential to limit demand for our services and adversely impact our future
operations and earnings.
Other federal agencies like the Federal Energy Regulatory Commission and state
authorities continue to heavily regulate the natural gas transportation market.
These regulations affect the price and terms for access to pipeline
transportation and the economics of natural gas production, transportation and
sales. To a lesser degree, transportation of crude oil by pipeline is also
subject to regulation. Any changes in these regulations that adversely affect
the market for natural gas or crude oil may adversely affect our business by
limiting demand for our services.
INSURANCE
Our operations are subject to the risks inherent in offshore marine activity.
These risks include personal injury and loss of life or property, environmental
accidents, mechanical failures and collisions. Damages arising from an
occurrence may in the future result in the assertion of potentially large claims
against us.
We maintain comprehensive insurance covering our assets and operations,
including marine employers' liability insurance and workers' compensation, at
levels we believe are consistent with industry standards. Our workers'
compensation and marine employers' liability insurance includes U.S.
Longshoremen and Harbor Workers Compensation Act and maritime and outer
continental shelf endorsements. In addition to our primary liability insurance,
we maintain excess and umbrella policies for up to a $30.0 million limit. We
also maintain other coverage for water pollution, automobile, property, hull and
commercial crimes. We believe that some risks are not insurable, or that
insurance to cover such risks is available only at rates that we do not consider
to be commercially reasonable. For example, we do not maintain insurance for the
cost of replacing the constructive total loss of vessels. We cannot assure you
that our insurance coverage will be adequate in all circumstances or against all
hazards, nor can we assure you that we will be able to maintain adequate
insurance coverage in the future at commercially reasonable rates or on
acceptable terms.
RISK FACTORS
A SUBSTANTIAL OR EXTENDED DECLINE IN OIL OR NATURAL GAS PRICES COULD RESULT IN
LOWER EXPENDITURES BY THE OIL AND NATURAL GAS INDUSTRY, THEREBY REDUCING OUR
REVENUE.
Demand for our services is greatly influenced by oil and natural gas prices.
Prices for oil and natural gas historically have been extremely volatile and
have reacted to changes in the supply of and demand of oil and natural gas,
domestic and worldwide economic conditions and political instability in oil
producing countries. Because of the volatility of these prices, demand for our
services may vary significantly. The capital expenditure programs of our
customers, which include major oil and natural gas companies and independent oil
and natural gas operators, have traditionally been influenced by the level of
oil and natural gas prices and the availability of funds. We are unable to
predict future oil and natural gas prices or the level of offshore construction
activity related to the industry.
An extended decline in the number of successful new wells on the Shelf could
result in lower capital expenditures by the oil and natural gas industry in this
area, thereby reducing our revenues. While oil and natural gas prices strongly
influence drilling activity, our customers need to successfully complete
commercially viable oil and natural gas wells. We are unable to predict how
successful a customer's drilling program will be.
The level of offshore drilling and exploration activity has varied substantially
in recent years, resulting in significant fluctuations in demand for our
services. Significant downturns in the oil and natural gas industry in the past
have adversely impacted our financial performance resulting in operating losses.
A significant or prolonged reduction in oil or
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natural gas prices in the future would likely depress offshore drilling and
development activity. A substantial reduction in this activity would reduce
demand for our services and have a material adverse effect on our financial
condition and results of operations.
OUR PLANS TO EXPAND OUR SERVICES INTO THE DEEPWATER MAY NOT BE SUCCESSFUL.
An important part of our growth strategy is our ability to successfully expand
our current services into the deepwater market. We are devoting significant
resources to this strategy. Specifically, we recently expanded our deepwater
capabilities by upgrading an existing vessel (the Midnight Eagle), purchasing a
vessel to convert to a specially designed and equipped deepwater offshore
construction vessel (the Midnight Express) and purchasing a vessel to convert to
a deepwater pipelay and subsea construction vessel (the Midnight Wrangler).
Additionally, we formed an employees team of deepwater specialists in our
Houston, Texas office. We may not be successful in obtaining or executing
contracts to provide deepwater services; furthermore, our plans to expand our
services into the deepwater will be dependent on our ability to obtain the
necessary capital to further implement our strategy.
WE MAY HAVE DIFFICULTY UPGRADING OUR EXISTING VESSELS AND ACQUIRING OR
CONSTRUCTING NEW VESSELS ON ACCEPTABLE TERMS, WHICH COULD ADVERSELY AFFECT OUR
STRATEGY TO GROW AND EXPAND OUR DEEPWATER SERVICES.
Upgrading our existing vessels and acquiring or constructing new vessels are key
elements of our strategy to expand our deepwater services. We have acquired and
plan to convert an existing vessel and have purchased another deepwater vessel.
We may pursue the acquisition of existing vessels for modification or the
acquisition of other companies with operations related to or complementary with
our current operations and our deepwater expansion strategy. We may not be able
to identify and acquire acceptable vessels or complementary companies on
financial or other terms acceptable to us. Additionally, we may not be able to
obtain financing for the acquisitions on acceptable terms. A significant or
prolonged reduction in oil or natural gas prices in the future would depress
offshore drilling and development activity and adversely affect our ability to
obtain financing for acquisitions. The construction and refurbishment of marine
equipment involves potential delays and increased costs due to unanticipated
delays in equipment deliveries, scheduling of service providers, equipment
condition problems and unforeseen difficulties with assembly or construction.
Any inability on our part to purchase additional marine equipment or other
complementary vessels on acceptable financial or other terms could have a
material adverse effect on our strategy to grow and expand our deepwater
services business.
THE CONTRACT FOR CONVERSION OF THE MIDNIGHT EXPRESS HAS NOT YET BECOME
EFFECTIVE.
Two conditions remain that Davie Maritime Inc. of Quebec, Canada (the
"Shipyard") must fulfill before the conversion contract for the Midnight Express
becomes effective. We are optimistic that these two conditions will be satisfied
and, to this end, have agreed to extend the date by which these conditions must
be met to April 2, 2003. If these conditions are not met, the conversion
contract will become null and void and we may have to submit the project for
re-bid. The delay resulting from re-bidding and re-awarding the contract could
result in substantial delay in delivery of the vessel and thus cause a delay in
the implementation of our deepwater strategy and the start of operations of the
Midnight Express. Additionally, the cost of the contract may increase and we
would incur costs to move the vessel to another shipyard. These delays and costs
could have a material adverse effect on our results of operations. Furthermore,
if we have to submit the project for re-bid, the project may not be awarded to a
shipyard located in Canada. Although we believe that we will be able to complete
the conversion in another Canadian shipyard, our inability to do so would result
in the loss of the Export Development Canada (EDC) financing of the project. If
we award the project to a shipyard that is not located in Canada, we will have
to secure additional financing for this project. We may not be able to secure
additional financing or may not be able to secure it on acceptable terms.
DELAYS OR COST OVERRUNS IN THE CONVERSION OF THE MIDNIGHT EXPRESS COULD
ADVERSELY AFFECT OUR BUSINESS, AND EXPECTED CASH FLOWS FROM THE MIDNIGHT EXPRESS
UPON COMPLETION MAY NOT BE AS IMMEDIATE OR AS HIGH AS EXPECTED.
The conversion of the Midnight Express is estimated to cost between $80.0
million and $90.0 million. The Midnight Express is currently scheduled to be
placed into service in early 2004, following sea trials. This project is subject
to the risks of delays or cost overruns inherent in vessel conversion projects.
These risks include:
o unforeseen quality or engineering problems;
o work stoppages;
o weather interference;
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o unanticipated cost increases;
o delays in receipt of necessary equipment; and
o inability to obtain the requisite permits or approvals.
Significant delays could have a material adverse effect on expected contract
commitments for this vessel and our future revenues and cash flows. We will not
receive any revenues or cash flows from the Midnight Express until it is placed
in service and customers enter into binding arrangements with us, potentially
several months or more after the vessel is completed. Furthermore, in the event
of a delay in the conversion, customer demand for the Midnight Express may not
be as high as we currently anticipate, and, as a result, our future cash flows
and operating results may be adversely affected.
WE HAVE COVENANTS WITHIN OUR DEBT INSTRUMENTS THAT MAY LIMIT OUR OPERATING AND
FINANCIAL OPPORTUNITIES.
Under the terms of our bank facility with Regions Bank, we must maintain a
tangible net worth of at least $60.0 million, a minimum debt service coverage
ratio of at least 1.20 to 1, a consolidated leverage ratio of no more than 2.00
to 1 and a consolidated current ratio of at least 1.30 to 1. Our potential
financing facility for the conversion of the Midnight Express also contains
various conditions to which we must adhere, including a minimum tangible net
worth of at least $60.0 million, a minimum debt service coverage ratio of at
least 1.20 to 1, a consolidated leverage ratio of no more than 2.00 to 1 and a
consolidated current ratio of 1.30 to 1. In addition, we are not allowed to
incur additional debt over $8.0 million without consent from Regions Bank. For
a more detailed discussion of our covenants, see "Management's Discussion and
Analysis of Financial Condition and Results of Operations - Liquidity and
Capital Resources." Furthermore, the terms of our bank facility and potential
financing facility may limit our ability to obtain future financing, continue
our expansion into the deepwater market and otherwise conduct necessary
corporate activities.
Our ability to meet the financial ratios and covenants depicted above can be
affected by events beyond our control and we may therefore not be able to
satisfy these requirements. If we fail to do so and we are unable to obtain a
waiver, our lenders will have various vested rights, including the ability to
accelerate the debt so that is payable immediately and exercise their rights
under the security provided to them by us. Any such acceleration would have a
material adverse effect on our financial position.
THE EXPECTED CASH FLOWS FROM THE MIDNIGHT WRANGLER MAY NOT BE AS IMMEDIATE OR AS
HIGH AS EXPECTED.
A significant delay in the introduction of this vessel into our active fleet
could have a material adverse effect on expected contract commitments for this
vessel and our future revenues and cash flows. We will not receive any revenues
or cash flows from the Midnight Wrangler until it is placed in service and
customers enter into binding arrangements with us, potentially several months or
more after the vessel is delivered. Furthermore, customer demand for the
Midnight Wrangler may not be as high as we currently anticipate, and, as a
result, our future cash flows and operating results may be adversely affected.
WE HAVE INCURRED LOSSES IN RECENT PERIODS AND MAY INCUR ADDITIONAL LOSSES IN THE
FUTURE.
We have, from time to time, incurred losses from operations, particularly during
periods of low industry-wide demand for marine construction services. Although
we were profitable in 2002 ($0.4 million net income), we incurred net losses of
$0.7 million in 2001 and $1.6 million in 2000. We may not be profitable in the
future. If we do achieve profitability in any period, we may not be able to
sustain or increase such profitability on a quarterly or annual basis. We had
negative cash flows from operations in 2002. Insufficient cash flows may
adversely affect our ability to fund anticipated capital expenditures required
to achieve profitability.
THE SEASONAL NATURE OF THE OFFSHORE CONSTRUCTION INDUSTRY MAY CAUSE OUR
QUARTERLY RESULTS TO FLUCTUATE.
The offshore construction industry in the Gulf of Mexico is seasonal as a result
of weather conditions and the timing of capital expenditures by our customers.
Typically, the greatest demand for offshore construction services is during the
period from May through September. Because of the seasonal nature of the
business, our quarterly results may fluctuate. In addition, the results of any
particular quarter are not necessarily indicative of annual results, future
quarters or continuing trends.
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OUR ORIGINAL ESTIMATES OF COSTS ASSOCIATED WITH OUR FIXED-PRICE CONTRACTS MAY BE
INCORRECT AND RESULT IN LOSSES ON PROJECTS AND, THEREFORE, ADVERSELY EFFECT OUR
OPERATING RESULTS.
Because of the nature of the offshore construction industry, the majority of our
projects are performed on a fixed-price basis. Changes in offshore job
conditions and variations in labor and equipment productivity may adversely
affect the costs and gross profit realized on a fixed-price contract and may
cause variations from the original estimates of those items. Since we expect
that our deepwater contracts may extend over several quarters, variations from
the original estimates of these items on our deepwater contracts may result in a
reduction or elimination of previously reported profits in future reporting
periods. In addition, we typically bear the risk of delays caused by adverse
weather conditions, excluding hurricanes and named tropical storms. The risks
inherent in the offshore construction industry may result in the profits we
realize on projects differing from those originally estimated and may result in
reduced profitability or losses on our projects.
WE DEPEND ON SEVERAL SIGNIFICANT CUSTOMERS, AND A LOSS OF ONE OR MORE
SIGNIFICANT CUSTOMERS COULD ADVERSELY AFFECT OUR OPERATING RESULTS.
Our customers consist primarily of major oil and natural gas companies and
independent oil and natural gas operators. In recent years, no single customer
has accounted for 10% or more of our revenues. In 2002, our two largest
customers accounted for 7.6% and 7.5%, respectively, of our revenues. The loss
of any one of our largest customers or a sustained decrease in demand by our
customers could result in a substantial loss of revenues and could have a
material adverse effect on our operating performance.
THE LOSS OF ANY MEMBER OF OUR SENIOR MANAGEMENT COULD ADVERSELY AFFECT OUR
RESULTS OF OPERATIONS.
Our success depends heavily on the continued services of our senior management.
Our senior management consists of a small number of individuals relative to
other comparable or larger companies. These individuals are Lyle G. Stockstill,
our Chief Executive Officer; Lana J. Hingle Stockstill, our Chief Administrative
Officer; Robert E. Fulton, our Chief Financial Officer; and Willie Bergeron, our
Chief Operating Officer. If we lost or suffered an extended interruption in the
services of one or more of our senior officers, our results of operations could
be adversely affected. Moreover, we may not be able to attract and retain
qualified personnel to succeed members of our senior management.
WE MAY BE UNABLE TO COMPETE SUCCESSFULLY WITH OTHER COMPANIES IN OUR INDUSTRY.
The industry in which we operate is highly competitive. Several of our
competitors are substantially larger than we are and have greater financial and
other resources. Price is the primary factor in determining which qualified
contractor is awarded the contract, although customers also consider the
availability and capabilities of equipment and the reputation and experience of
the contractor. Competitors with greater financial resources may be willing to
sustain losses on projects to prevent further market entry by competitors, to
cover the fixed costs of their fleets or to avoid the expense of temporarily
idling vessels. Marine construction vessels have few alternative uses and
relatively high fixed costs, whether or not they are in operation. As we
increase the portion of our operations conducted in deepwater, we will face
additional competitors, many of whom have more vessels and greater experience in
deepwater operations. As large international companies relocate vessels to the
Gulf of Mexico, levels of competition may increase and our business involving
deepwater projects in the Gulf of Mexico could be adversely affected.
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OFFSHORE CONSTRUCTION IS SUBJECT TO VARIOUS OPERATING RISKS, AND WE MAY LACK
ADEQUATE INSURANCE TO COVER THESE OPERATING RISKS.
Offshore construction involves a high degree of operational risk. Hazards, such
as vessels capsizing, sinking, grounding, colliding and sustaining damage from
severe weather conditions, are inherent in marine operations. In addition,
vessels engaged in pipeline operations can disrupt existing pipelines. These
hazards can cause personal injury or loss of life, severe damage to and
destruction of property and equipment, pollution or environmental damage and the
suspension of production operations. The failure of offshore pipelines and
structural components during and after installation can also result in similar
injuries and damages. Our insurance may not be sufficient or effective to
protect us from these operating risks. A successful claim for damages resulting
from a hazard for which we are not fully insured could have a material adverse
effect on us. Moreover, we may not be able to maintain adequate insurance in the
future at rates that we consider reasonable.
REGULATORY AND ENVIRONMENTAL COMPLIANCE COSTS AND LIABILITIES COULD ADVERSELY
AFFECT OUR BUSINESS.
Our operations are subject to and affected by various types of governmental
regulation, including numerous federal, state and local environmental protection
laws and regulations. Compliance with these laws and regulations may be
difficult and expensive. In addition, significant fines and penalties may be
imposed in the event of any noncompliance. Some environmental laws impose strict
liability for remediation of spills and releases of oil and hazardous
substances, rendering a party liable for environmental damages without regard to
its negligence or fault. Sanctions for noncompliance with these laws and
regulations may include revocation of permits, corrective action orders,
administrative or civil penalties and criminal prosecutions. These laws and
regulations may expose us to liability for the conduct of or conditions caused
by others, including our subcontractors, or for our acts that were in compliance
with all applicable laws at the time these acts were performed. The adoption of
laws or regulations curtailing exploration and development drilling for oil and
natural gas for economic, environmental or other policy reasons could adversely
affect our operations by limiting demand for our services. In addition, new
legislation or regulations or changes in existing regulations may adversely
affect our future operations and earnings.
IF WE ARE UNABLE TO ATTRACT AND RETAIN SKILLED WORKERS OUR BUSINESS WILL BE
ADVERSELY AFFECTED.
Our ability to remain productive and profitable depends substantially upon our
ability to continue to retain and attract project managers, project engineers
and skilled construction workers such as divers, welders, pipefitters, DP
operators and equipment operators. Our ability to expand our operations is
impacted by our ability to increase our labor force. The demand for skilled
workers is currently high and the supply is limited. A significant increase in
the wages paid or benefits offered by competing employers could result in a
reduction in our skilled labor force, increases in our employee costs, or both.
If either of these events occur, our capacity and profitability could be
diminished and our growth potential could be impaired. Furthermore, as a result
of the terrorist attacks on September 11, 2001, it has become increasingly
difficult to obtain and retain visas for foreign employees. Any additional
controls could increase our costs and may affect our ability to hire foreign
employees.
A TERRORIST ATTACK OR THE CURRENT WAR IN IRAQ COULD HAVE A MATERIAL ADVERSE
EFFECT ON OUR BUSINESS.
The September 11, 2001 terrorist attacks in the United States were unprecedented
events that created many economic and political uncertainties. The long-term
effects of those attacks on our business are unknown. The potential for future
terrorist attacks, the national and international response to terrorist attacks,
and other acts of war or hostility have created many additional economic and
political uncertainties, which could adversely affect our business for the short
or long-term in ways that cannot presently be predicted. Furthermore, the war
with Iraq and the possibility for further political instability in the Middle
East may delay our entry into international markets.
THE OWNERSHIP OF OUR COMMON STOCK BY OUR PRINCIPAL STOCKHOLDERS WILL LIMIT THE
INFLUENCE OF PUBLIC STOCKHOLDERS.
Mr. and Mrs. Stockstill and their family trusts beneficially owned at December
31, 2002 approximately 59% of our outstanding shares of common stock.
Accordingly, these stockholders have the ability to control the election of our
directors and the outcome of all other matters submitted to a vote of our
stockholders.
ARTHUR ANDERSEN LLP, OUR FORMER AUDITORS, AUDITED CERTAIN FINANCIAL INFORMATION
INCLUDED IN THIS FORM 10-K. IN THE EVENT SUCH FINANCIAL INFORMATION IS LATER
DETERMINED TO CONTAIN FALSE OR MISLEADING STATEMENTS, YOU MAY BE UNABLE TO
RECOVER DAMAGES FROM ARTHUR ANDERSEN LLP.
Arthur Andersen LLP completed its audit of our financial statements for the year
ended December 31, 2001, and issued its report with respect to such financial
statements on January 25, 2002 (except with respect to Note 16, as to which the
date was March 1, 2002). In June 2002, our Board of Directors, at the
recommendation of our Audit Committee, approved the appointment of Ernst & Young
LLP as our independent public accountants to audit our financial statements for
fiscal year 2002. Ernst & Young replaced Arthur Andersen, which had served as
our independent auditors since 1997. Arthur Andersen audited the financial
statements that we include in the Form 10-K as of December 31, 2001 and for each
of the years in the two-year period ended December 31, 2001, as set forth in
their report herein.
In June 2002, Arthur Andersen was convicted of obstructing justice, which is a
felony offense. The Securities and Exchange Commission (the "SEC") prohibits
firms convicted of a felony from auditing public companies. Arthur Andersen is
thus unable to consent to the incorporation of its opinions with respect to this
Form 10-K. Under these circumstances, Rule 437a under the Securities Act permits
us to file this Form 10-K, which is incorporated by reference into a
registration statement we have on file with the SEC, without a written consent
from Arthur Andersen. The Securities Act of 1933 (the "Securities Act"),
provides that if part of a registration statement at the time it becomes
effective contains an untrue statement of material fact, or omits a material
fact required to be stated therein or necessary to make the statements therein
not misleading, any person acquiring a security pursuant to such registration
statement (unless it is proved that at the time of such acquisition such person
knew of such untruth or omission) may assert a claim against, among others, an
accountant who has consented to be named as having certified any part of the
registration statement or as having prepared any report for use in connection
with the registration statement. As a result, with respect to transactions in
our securities pursuant to our registration statements that occur after this
Form 10-K is filed with the SEC, Arthur Andersen will not have any liability
under the Securities Act for any untrue statements of a material fact contained
in the financial statements audited by Arthur Andersen or any omissions of a
material fact required to be stated therein. Accordingly, you would be unable to
assert a claim against Arthur Andersen under the Securities Act.
- 18 -
EXECUTIVE OFFICERS
The following table provides information regarding our executive officers as of
March 25, 2003:
NAME AGE POSITION(s)
----------------------------------------- --- ----------------------------------------------------
Lyle G. Stockstill....................... 59 Chairman of the Board and Chief Executive Officer
Lana J. Hingle Stockstill................ 59 Chief Administrative Officer, Secretary and Director
Robert E. Fulton......................... 52 Chief Financial Officer
Willie Bergeron.......................... 53 Chief Operating Officer
Lyle G. Stockstill is one of our co-founders and has served as our Chairman of
the Board and Chief Executive Officer since 1978. Mr. Stockstill has over 38
years of experience in all aspects of offshore pipelay and construction
operations. Mr. Stockstill has previously held positions at Brown & Root, Inc.
and Taylor Diving, Inc. and has worked both domestically and internationally.
Mr. Stockstill is the husband of Lana J. Hingle Stockstill.
Lana J. Hingle Stockstill is one of our co-founders and has served as Senior
Vice President - Administration, Secretary and as a director since 1978. In
March 2003, her title was changed to Chief Administrative Officer. Mrs.
Stockstill has 30 years of experience handling our administrative duties and the
administrative duties of other oil service companies. Mrs. Stockstill holds a
Bachelor of Arts degree from Louisiana State University. Mrs. Stockstill is the
wife of Lyle G. Stockstill.
Robert E. Fulton has served as our Chief Financial Officer since August 2002.
From April 2001 to July 2002, Mr. Fulton was employed by Global Industries,
Ltd., an oilfield services and pipeline construction company, as Vice President
and Treasurer. From January 1980 to March 2001, Mr. Fulton was employed by
McDermott International, Inc., an international offshore contractor, in various
finance positions, most recently serving as Assistant Treasurer. Mr. Fulton has
28 years of domestic and international finance experience and holds a Bachelor
of Arts degree from the University of Notre Dame and a MBA Degree from the
American Graduate School of International Management.
Willie Bergeron joined our company in September 1995 as a Project Manager. Mr.
Bergeron was promoted to General Manager of Operations in December 1997 and then
to General Manager - Shallow Water Division in March 1999. In September 2000,
Mr. Bergeron was promoted to Operations Manager for both shallow and deepwater
activities and in July 2001 was promoted to Vice President - Operations. In
March 2003, his title was changed to Chief Operating Officer. From 1988 to 1995,
Mr. Bergeron was employed in the areas of operations management and engineering
by McDermott International, Inc. Prior to that, Mr. Bergeron co-owned a civil
engineering firm that conducted offshore, commercial and residential
engineering. Mr. Bergeron has 25 years of oilfield related experience and holds
a degree in Engineering Technology from Nicholls State University.
ITEM 2. PROPERTIES
FLEET
For information regarding our vessels, please read "Item 1. Business - Our
Fleet," which information is incorporated herein by reference.
FACILITIES
Our corporate headquarters are located in Gretna, Louisiana, near New Orleans.
We also maintain a commercial office in Houston, Texas, a training facility in
Harvey, Louisiana (we will not renew the training facility lease in April 2003
as our expansion in office space at our corporate office initiated in 2002
included space for training purposes), a logistics support
- 19 -
base and fabrication yard in Dulac, Louisiana, a deepwater support facility in
New Orleans, Louisiana and a rental property for client and provider
entertainment purposes in Empire, Louisiana. The lease for the deepwater support
facility is through a month-to-month agreement whereby we pay a flat monthly fee
plus additional charges based on usage by our vessels. All of our facilities are
leased. The following chart describes our facilities as of December 31, 2002:
APPROXIMATE TERMINATION
LOCATION FUNCTION SIZE DATE OF LEASE
--------------------------------- ---------------------- --------------- --------------
Gretna, Louisiana ............... Corporate Office 13,400 sq. ft. December 2005
Houston, Texas .................. Commercial Office 4,200 sq. ft. May 2003
Harvey, Louisiana ............... Training Facility 4,500 sq. ft. April 2003
Dulac, Louisiana ................ Logistics Support Base 21.9 acres October 2003
and Fabrication Yard
New Orleans, Louisiana .......... Deepwater Support Facility 42,500 sq. ft. Monthly
Empire, Louisiana ............... Client and Provider
Entertainment Facility 2,400 sq. ft. December 2007
ITEM 3. LEGAL PROCEEDINGS
We are involved in legal proceedings arising in the ordinary course of business.
Although we cannot give you any assurance with respect to the ultimate outcome
of such legal actions, in our opinion, these matters will not have a material
adverse effect on our financial position or results of operations.
We have been named as a defendant in a stockholder class action suit filed by
purported stockholders regarding our initial public offering. This lawsuit, Karl
L. Kapps, et. al. v. Torch Offshore, Inc. et. al., No. 02-00582, which seeks
unspecified monetary damages, was filed on March 1, 2002 in U.S. District Court
for the Eastern District of Louisiana. The lawsuit was dismissed on December 19,
2002 for failure to state a claim upon which relief could be granted. The
plaintiff has appealed to the U.S. Court of Appeals for the Fifth Circuit. We
believe the allegations in this lawsuit are without merit and we intend to
continue to vigorously defend this lawsuit. Even so, an adverse outcome in this
class action litigation could have a material adverse effect on our financial
condition or results of operations.
We have been named as a defendant in a lawsuit (Bluffview Capital, LP v. Torch
Offshore, Inc., No. 2002-7662, filed in the 134th Judicial District Court,
Dallas County, Texas on August 26, 2002) brought by a former service provider.
The plaintiff was originally hired to assist us in obtaining financing, among
other services. We terminated the relationship and are disputing the plaintiff's
interpretation of certain provisions regarding the services to be provided and
the calculation of fees allegedly earned. It is our position that we have
complied with all of the provisions of the contract and we intend to continue to
vigorously defend our position in this matter. Nevertheless, an adverse outcome
in the litigation could have an adverse effect on our results of operations.
We terminated our charter of the Midnight Hunter on January 24, 2003, as, among
other things, the vessel did not meet certain specifications as outlined in the
charter agreement and this prevented us from performing some types of work. We
filed a lawsuit (Torch Offshore, L.L.C. v. The M/V Midnight Hunter and Cable
Shipping, Inc., et al., No. 03-0343, filed in the United States District Court,
Eastern District of Louisiana on February 4, 2003) seeking an order, which was
granted by the court, attaching and arresting the Midnight Hunter as security
for our claims related to such termination. A $1.5 million standby letter of
credit issued to secure our payments under the charter remains outstanding. The
claims will be settled by arbitration in London, England. Management believes
the amount of the claim is justified and we intend to vigorously pursue this
matter. Nevertheless, an adverse outcome from the litigation/arbitration could
have an adverse effect on our results of operations.
- 20 -
We filed a lawsuit (Torch Offshore, Inc. v. Newfield Exploration Company, No.
03-0735, filed in the United States District Court, Eastern District of
Louisiana on March 13, 2003) against Newfield Exploration Company (Newfield)
claiming damages of approximately $2.1 million related to work completed for
Newfield in the Gulf of Mexico at Grand Isle Block 103-A. Our lawsuit alleges
that we did not receive all compensation to which we were entitled pursuant to
the contract. As of December 31, 2002, we had recorded an amount attributable to
this claim based upon our contractual rights under our agreement with Newfield.
We intend to vigorously pursue this matter, the ultimate resolution of which
could materially impact currently recorded amounts in the future.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted to a vote of our stockholders during the quarter ended
December 31, 2002.
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
Our Common Stock, $0.01 par value, is traded on the NASDAQ National Market
System under the symbol "TORC". At March 25, 2003, there were approximately
1,300 holders of record of our Common Stock.
The following table sets forth the high and low sales price per share of our
Common Stock, as reported by the NASDAQ National Market, for each fiscal quarter
since our initial public offering in June 2001:
HIGH LOW
--------- --------
2003
First Quarter (through March 25, 2003) $ 6.19 $ 4.90
2002
Fourth Quarter ....................... $ 5.79 $ 4.31
Third Quarter ........................ $ 7.95 $ 4.77
Second Quarter ....................... $ 9.54 $ 7.14
First Quarter ........................ $ 9.25 $ 5.45
2001
Fourth Quarter ....................... $ 6.40 $ 4.03
Third Quarter ........................ $ 10.25 $ 4.67
Second Quarter ....................... $ 19.00 $ 9.20
We do not intend to pay cash dividends on our Common Stock for the foreseeable
future. We currently intend to retain earnings, if any, for the future operation
and development of our business. See "Item 7. Management's Discussion and
Analysis of Financial Condition and Results of Operations."
ITEM 6. SELECTED FINANCIAL DATA
The following table presents selected financial and operating data of Torch
Offshore, Inc. for the periods shown. You should read the following data in
conjunction with the more detailed information appearing in "Item 7.
Management's Discussion and Analysis of Financial Condition and Results of
Operations" and our financial statements, including the notes thereto, appearing
elsewhere in this Form 10-K.
- 21 -
(in thousands, except per share and operating data) YEARS ENDED DECEMBER 31,
STATEMENT OF OPERATIONS DATA 2002 2001 2000 1999 1998
---------------------------------------------------- ----------- ----------- ----------- ----------- -----------
Revenues ........................................... $ 67,990 $ 59,052 $ 46,205 $ 21,252 $ 39,224
Cost of sales ...................................... 53,341 43,190 34,011 21,190 25,198
----------- ----------- ----------- ----------- -----------
Gross profit(1) .................................... 14,649 15,862 12,194 62 14,026
Depreciation and amortization ...................... 7,540 6,376 4,941 3,469 2,187
General and administrative ......................... 4,767 3,982 3,759 3,327 2,275
Other operating (income) expense ................... 1,966 950 954 1,741 (2)
----------- ----------- ----------- ----------- -----------
Operating income (loss) ............................ $ 376 $ 4,554 $ 2,540 $ (8,475) $ 9,566
=========== =========== =========== =========== ===========
Interest income (expense), net ..................... 232 (1,174) (3,813) (1,413) (491)
Extraordinary loss on early extinguishment of
debt ............................................. -- (498) -- (676) --
Net income (loss) attributable to common
stockholders ..................................... $ 395 $ (741) $ (1,578) $ (10,568) $ 9,032
=========== =========== =========== =========== ===========
Earnings (loss) per share:
Basic ............................................ $ 0.03 $ (0.07) $ (0.21) $ (1.41) $ 1.20
=========== =========== =========== =========== ===========
Diluted .......................................... $ 0.03 $ (0.07) $ (0.21) $ (1.41) $ 1.15
=========== =========== =========== =========== ===========
Common equivalent shares:
Basic ............................................ 12,692 10,845 7,505 7,505 7,505
=========== =========== =========== =========== ===========
Diluted .......................................... 12,695 10,845 7,505 7,505 7,886
=========== =========== =========== =========== ===========
Cash dividends per common share .................... $ -- $ -- $ -- $ 0.04 $ 0.53
=========== =========== =========== =========== ===========
OTHER FINANCIAL DATA
----------------------------------------------------
EBITDA Recap:
Net income (loss) attributable to common
stockholders .................................... $ 395 $ (741) $ (1,578) $ (10,568) $ 9,032
Income tax expense ............................... 213 3,433 -- 4 43
Interest (income) expense, net ................... (232) 1,174 3,813 1,413 491
Depreciation and amortization .................... 7,540 6,376 4,941 3,469 2,187
Extraordinary loss on early extinguishment of
debt ............................................ -- 498 -- 676 --
Preferred unit dividends and accretion ........... -- 190 305 -- --
Vessel charges ................................... 1,052 950 -- -- --
----------- ----------- ----------- ----------- -----------
EBITDA(2) .......................................... $ 8,968 $ 11,880 $ 7,481 $ (5,006) $ 11,753
=========== =========== =========== =========== ===========
Net cash provided by (used in):
Operating activities ............................. (2,279) 2,419 1,746 (4,206) 9,997
Investing activities ............................. (24,229) (13,741) (2,538) (6,451) (22,047)
Financing activities ............................. 2,342 34,929 463 11,557 11,467
BALANCE SHEET DATA (AT END OF PERIOD)
----------------------------------------------------
Working capital .................................... $ 12,018 $ 30,641 $ (10,103) $ (7,772) $ (663)
Property, net ...................................... 67,561 49,179 40,202 41,120 31,702
Total assets ....................................... 101,904 92,755 57,988 54,069 47,586
Long-term debt, excluding current portion .......... 46 -- 23,957 29,522 17,915
Mandatorily redeemable convertible preferred
units(3) ......................................... -- -- 4,678 -- --
Stockholders' equity ............................... 79,867 81,041 6,311 7,889 18,723
- 22 -
(in thousands, except per share and operating data) YEARS ENDED DECEMBER 31,
OPERATIONS DATA 2002 2001 2000 1999 1998
---------------------------------------------------- ----------- ----------- ----------- ----------- -----------
Available revenue days(4) .......................... 3,181 2,817 2,603 1,953 1,521
Revenue days worked(5) ............................. 2,125 1,979 1,820 981 1,092
Total pipelay mileage .............................. 227 190 194 117 137
Average revenue per mile of pipe laid .............. $ 256,300 $ 262,100 $ 207,800 $ 155,600 $ 236,482
Average miles per pipelay job ...................... 3.6 2.9 3.0 3.8 3.1
Total vessels in operation (at end of period)(6).... 10 9 8 6 6
AVERAGE PRICE(7)
---------------------------------------------------- ----------- ----------- ----------- ----------- -----------
Crude oil (per barrel) ............................. $ 26.15 $ 25.96 $ 30.28 $ 19.32 $ 14.40
Natural gas (per thousand cubic feet) .............. $ 3.37 3.96 4.31 2.31 2.16
----------
(1) Gross profit is revenues less cost of sales.
(2) EBITDA represents earnings before net interest, income taxes, depreciation
and amortization. The EBITDA presented above is also adjusted to exclude
charges in 2002 of $0.9 million resulting from the write off of certain
costs due to the termination of the Midnight Hunter charter agreement and
$0.2 million resulting from the write off of certain financing costs related
to the Midnight Express and $1.0 million in 2001 resulting from the write
off of certain deferred costs related to the Midnight Warrior project.
EBITDA is presented here to provide additional information about our
operations. EBITDA is not a calculation based on generally accepted
accounting principles and should not be considered as an alternative to net
income, as an indicator of our operating performance or as an alternative to
cash flow as a better measure of liquidity. In addition, our EBITDA
calculation may not be comparable to similarly titled measures of other
companies. We have disclosed EBITDA because we use this measure as an
internal benchmark against certain performance objectives and to provide
investors and creditors additional information in assessing our business in
comparison to industry and other market competitive standards.
(3) Represents mandatorily redeemable convertible preferred membership units
that were exchanged for common stock in 2001 as part of the contribution of
membership interests in Torch Offshore, L.L.C. to Torch Offshore, Inc.
(4) Represents total calendar days for each vessel less any days a vessel was
nonoperational.
(5) Number of days vessels are offshore performing services, in transit or
waiting on inclement weather, while under contract.
(6) Includes the Midnight Hunter as of December 31, 2002; however, the charter
of the Midnight Hunter was terminated in January 2003.
(7) Based on the monthly average closing current contract prices posted by the
NYMEX.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
The following discussion and analysis should be read in conjunction with our
financial statements and related notes included elsewhere in this Annual Report.
The discussion below contains forward-looking statements that involve risks and
uncertainties. Our actual results could differ materially from those expressed
or implied in this Form 10-K. Factors that could cause or contribute to such
differences include, but are not limited to, those discussed above under the
captions "Forward-Looking Statements" and "Item 1 Business - Risk Factors."
OVERVIEW
We provide subsea construction services in connection with the in-field
development of offshore oil and natural gas reservoirs. We are a leading service
provider in our market niche of installing and maintaining small diameter
flowlines and related infrastructure on the Shelf. Over the last few years, we
have expanded our operations, fleet capabilities and management expertise to
enable us to provide deeper water services analogous to the services we provide
on the Shelf.
Since 1997, we have increased the size of our total fleet from three to eleven
construction and service vessels. In 1998, we added two diving support vessels
and one supply/diving support vessel. In 2000, we added one fully redundant
dynamically positioned, or DP-2, pipelay/bury barge (the Midnight Eagle) and one
DP-2 subsea construction vessel (the Midnight Arrow). In June 2001, we purchased
a pipelay/bury barge, the Midnight Rider, which increased our capabilities on
the Shelf and was placed into service in late 2001. In 2002, we completed the
acquisition of a 520-foot vessel from
- 23 -
Smit International. This vessel will be converted to a DP-2 offshore
construction vessel with our patent-pending pipelay system and renamed the
Midnight Express. In December 2002, we committed to purchase a cable-lay vessel,
renamed the Midnight Wrangler, for the purpose of deepwater pipelay and subsea
construction. We took possession of this vessel in March 2003. This vessel will
enter our active fleet during the second quarter of 2003 after various
modifications to the vessel are made. We are actively seeking opportunities to
expand our fleet either through construction or acquisition of vessels.
In addition, we purchased the Midnight Gator, a supply barge, in September 2002.
We are currently converting this piece of equipment into a sand dredge and it
will become available for use in the second quarter of 2003 for the purpose of
jetting trenches for pipe burial in shallow waters.
In November 2002, we signed a contract to provide pipeline installation support
in the Boston, Massachusetts Harbor. The contract commenced in the fourth
quarter of 2002 and should last for a period of five to six months from the date
of commencement. The contract calls for the Midnight Rider to work outside of
Gulf of Mexico waters for the duration of the contract. The contract provides
for the mobilization and demobilization of the vessel in addition to the pipelay
and burial work to be completed by the Midnight Rider.
FACTORS AFFECTING RESULTS OF OPERATIONS
The demand for subsea construction services primarily depends on the prices of
oil and natural gas. These prices reflect the general condition of the industry
and influence the willingness of our customers to spend capital to develop oil
and natural gas reservoirs. We are unable to predict future oil and natural gas
prices or the level of offshore construction activity related to the industry.
In addition to the prices of oil and natural gas, we use the following leading
indicators, among others, to forecast the demand for our services:
o the offshore mobile and jack-up rig counts;
o forecasts of capital expenditures by major and independent oil and natural
gas companies; and
o recent lease sale activity levels.
Even when demand for subsea construction services is strong, several factors may
affect our profitability, including the following:
o competition;
o equipment and labor productivity;
o weather conditions;
o contract estimating uncertainties;
o global economic and political circumstances; and
o other risks inherent in marine construction.
Although greatly influenced by overall market conditions, our fleet-wide
utilization is generally lower during the first half of the year because of
winter weather conditions in the Gulf of Mexico. Accordingly, we endeavor to
schedule our drydock inspections and routine and preventative maintenance during
this period. Additionally, during the first quarter, a substantial number of our
customers finalize capital budgets and solicit bids for construction projects.
For this reason, individual quarterly/interim results are not necessarily
indicative of the expected results for any given year.
- 24 -
In the life of an offshore field, capital is allocated to the development of a
well following a commercial discovery. The time that elapses between a
successfully drilled well and the development phase, in which we participate,
varies depending on the water depth of the field. On the Shelf, demand for our
services generally follows drilling activities by three to twelve months. We
have noticed that demand for pipeline installation for deepwater projects
exceeding 1,000 feet of water depth generally follows drilling activities by
eighteen months to three years. These deepwater installations typically require
much more engineering design work than do Shelf installations.
OUTLOOK
We experienced positive earnings in 2002 and expect a similar result in 2003,
although we expect these earnings to be minimal. We believe the first half of
2003 will be a period of minimal activity with a possibility for an increase in
activity during the second half of the year. Despite the relatively high
commodity prices of both oil and natural gas, the 2002 exploration and
production spending budgets of the oil and natural gas companies remained
relatively flat and are expected to maintain that pattern in the near term due
to the many uncertainties regarding the current state of the world's economies
and current war in Iraq. We believe that our future financial and operating
results will continue to be highly dependent on overall market conditions in the
oil and natural gas industry.
We believe that the Shelf will benefit from recently passed royalty relief
regulations, which provide certain benefits to companies performing deep
drilling on the Shelf. We anticipate that this benefit may entice certain
independent oil and natural gas operators to increase their drilling for natural
gas on the Shelf. In addition, we anticipate that the Gulf of Mexico offshore
construction industry will benefit from improved long-term industry
fundamentals. We believe that a combination of factors, such as the expected
increase in worldwide energy demand, decreased levels of natural gas storage,
positive Shelf and deepwater forecasts for capital expenditures in 2004 and our
strong market presence, positions us well for the future. The extensive
transportation infrastructure present on the Shelf facilitates the development
of incremental fields that can be tied into existing trunklines originally
constructed to service fields that are now in the process of decline, which
favors our Shelf market niche strategy. The additions to our active fleet of the
Midnight Wrangler in 2003 and the Midnight Express in early 2004 also positions
us to take on the challenges and opportunities of the deepwater market in the
near future.
Natural gas consumption in the United States is expected to continue to increase
over the next decade, as it did during 2002, leading to a further depletion of
levels of natural gas storage. A large portion of this continued expansion is
expected to come from the growth in electric power requirements and overall
population growth. Environmental and economic considerations dictate that a
large percentage of this increased electric power will come from newly
constructed gas-fired power generation facilities. Oil consumption should also
remain relatively stable in the near-term. Management believes that significant
new capital must be continually invested in field exploration and development in
order to maintain, much less grow, existing oil and natural gas energy
production levels to meet these growing demands.
These increased demands for natural gas and the dominant role of independent oil
and natural gas operators on the Shelf should allow the Gulf of Mexico to
maintain and even increase its position as a major source of North American
natural gas supplies for the intermediate term. According to the MMS,
approximately 77% of the natural gas production in the first nine months of 2001
in the Gulf of Mexico came from shallow water fields. In addition, technological
advances have enabled oil and natural gas companies to improve exploration
success rates. Management believes that the higher demand, improved
technologies, and higher natural gas prices will permit the exploration for and
the development of additional marginal prospects, resulting in increased
activity on the Shelf where we already have a strong market position.
While the economic fundamentals of the Shelf are positive, major oil and natural
gas companies and large independent oil and natural gas operators are
increasingly focusing their exploration and development efforts on frontier
areas, particularly the deepwater regions of the Gulf of Mexico and the coasts
of South America and West Africa. These regions offer greater oil and natural
gas reserve and production growth potential relative to the existing Shelf
regions. Focusing on the Gulf of Mexico, deepwater production has been much more
prolific and oil prone than on the Shelf, as approximately 55% of the oil
production from the Gulf of Mexico was from deepwater fields during the first
nine months of 2001
- 25 -
according to the MMS (the MMS classifies deepwater as 1,000 feet deep and
beyond). These worldwide deepwater basins are one of the few non-OPEC areas to
have major reserve potential, with numerous individual discoveries expected to
produce more than one billion barrels each. There have already been several
deepwater fields identified for development and various other projects are under
contemplation. The completion of these deepwater projects will require
multi-billion dollar expenditures and will result in additional wells; subsea
trees, templates and manifolds; subsea control lines; flowlines; risers; and
fixed and floating platforms.
RESULTS OF OPERATIONS
COMPARISON OF THE YEAR ENDED DECEMBER 31, 2002 TO THE YEAR ENDED DECEMBER 31,
2001
Revenues. Revenues were $68.0 million for the year ended December 31, 2002
compared to $59.1 million for the year ended December 31, 2001, an increase of
15.1%. This increase resulted from an overall increase in the number of revenue
days worked by the fleet, as the capacity of the fleet was expanded during 2002.
The Midnight Rider was in the fleet for all of 2002, contributing 303 revenue
days, versus availability during only a portion of 2001, when it contributed 25
revenue days. The Midnight Hunter was an active part of our fleet and added 107
revenue days during the second half of 2002. The overall fleet-wide improvement
for the number of revenue days worked was 7.4%, as the fleet worked 2,125 days
in 2002 as compared to 1,979 days in 2001. The average vessel utilization of the
fleet decreased slightly during 2002 to 66.8% versus 70.3% in 2001. In addition,
average pricing realization levels (revenues divided by revenue days) for our
services in 2002 were approximately 7.2% higher than 2001 levels per revenue day
worked.
Gross Profit. Gross profit (defined as revenues less cost of sales) was $14.6
million (21.5% of revenues) for the year ended December 31, 2002, compared to
$15.9 million (26.9% of revenues) for the year ended December 31, 2001, a
decrease of 7.6%. Cost of sales consists of job related costs such as vessel
wages, insurance and repairs and maintenance. The decrease in the overall gross
profit as a percentage of revenue was caused by an increase in job related
insurance costs, higher offshore wages and benefits, increased fuel costs, and
higher subcontract costs.
Depreciation and Amortization. Depreciation and amortization expense was $7.5
million for the year ended December 31, 2002, compared to $6.4 million for the
year ended December 31, 2001, an increase of 18.3%. This increase primarily
reflects a full year of depreciation on the Midnight Rider in 2002, versus only
a partial year of depreciation in 2001. In addition, depreciation on the
equipment added to the Midnight Hunter commenced in the third quarter of 2002,
the depreciation on the Midnight Eagle increased due to the addition of
equipment during 2002, and there was an increase in depreciation related to
computer equipment.
General and Administrative Expenses. General and administrative expenses were
$4.8 million (7.0% of revenues) for the year ended December 31, 2002 compared to
$4.0 million (6.7% of revenues) for the year ended December 31, 2001, an
increase of 19.7%. The increase in 2002 as compared to 2001 was a result of
higher consulting fees, investor relation costs and franchise taxes related to
being a public entity for the entire year along with higher insurance premiums
and wages.
Other Operating Expense. Other operating expense was $2.0 million for the year
ended December 31, 2002, compared to $1.0 million of other operating expense for
the year ended December 31, 2001. The other operating expense in 2002 relates
primarily to charges resulting from the write off of certain costs due to the
termination of the Midnight Hunter charter agreement and the write off of
certain financing costs related to the Midnight Express. In addition, the other
operating expense includes a $0.9 million charge relating to an increase in our
allowance for doubtful accounts. The other operating expense in 2001 relates to
the charge resulting from the write off of certain costs related to the Midnight
Warrior project.
Interest Expense, Net. Net interest income was $0.2 million for the year ended
December 31, 2002, compared to net interest expense of $1.2 million for the year
ended December 31, 2001. We capitalized all of our 2002 interest costs totaling
$0.1 million, in relation to the construction of the Midnight Express. The
interest expense in
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2001 was incurred before we retired all outstanding debt in June 2001 with the
proceeds of our initial public offering. In addition, the interest income on the
remaining proceeds of our initial public offering totaled $0.5 million.
Income Taxes. For the year ended December 31, 2002, we recorded a $0.2 million
income tax provision at a 35% effective tax rate. In connection with our initial
public offering, we became subject to corporate level taxation. As such, we
recorded a one-time $2.6 million tax charge based upon the cumulative book and
tax basis differences at that time. Additionally, we recorded a $0.8 million
income tax provision, at a 35% effective rate, on pretax earnings subsequent to
our initial public offering. If we had been subject to payment of income taxes
for the entire period, we would have recorded an additional charge of $0.3
million for the year ended December 31, 2001.
Extraordinary Loss. In June 2001, we completed our initial public offering
resulting in the retirement of all outstanding debt balances. In connection with
this extinguishment of debt, we recognized a $0.5 million (net of taxes of $0.3
million) charge on the early extinguishment of debt (see Note 7 to the financial
statements).
Net Income (Loss) Attributable to Common Stockholders. Net income to common
stockholders for the year ended December 31, 2002 was $0.4 million, compared
with a net loss of $0.7 million in 2001, including a $0.2 million charge for
preferred dividends in 2001.
COMPARISON OF THE YEAR ENDED DECEMBER 31, 2001 TO THE YEAR ENDED DECEMBER 31,
2000
Revenues. Revenues were $59.1 million for the year ended December 31, 2001,
compared to $46.2 million for the year ended December 31, 2000, an increase of
27.8%. This increase resulted from the generally stronger Shelf natural gas
market for the first half of 2001 and an increase in the number of revenue days
worked. The overall fleet-wide improvement for the number of revenue days worked
was 8.7% as the fleet worked 1,979 days in 2001 as compared to 1,820 days in
2000. The average vessel utilization of the fleet remained steady at 70.3%
versus 70.4% in 2000. In addition, average pricing levels (revenues divided by
revenue days) for our services in 2001 were 17.5% higher than 2000 levels.
Gross Profit. Gross profit was $15.9 million (26.9% of revenues) for the year
ended December 31, 2001, compared to $12.2 million (26.4% of revenues) for the
year ended December 31, 2000, an increase of 30.1%. This increase resulted
directly from the increase in revenues, with the gross profit as a percentage of
revenues remaining steady. Cost of sales consists of job related costs such as
vessel wages, insurance and repairs and maintenance.
Depreciation and Amortization. Depreciation and amortization expense was $6.4
million for the year ended December 31, 2001, compared to $4.9 million for the
year ended December 31, 2000, an increase of 29.0%. This increase primarily
reflects a partial year of depreciation in 2001 on the Midnight Rider and a full
year of amortization on the drydocking of the Midnight Carrier, which occurred
in late 2000.
General and Administrative Expenses. General and administrative expenses were
$4.0 million (6.7% of revenues) for the year ended December 31, 2001, compared
to $3.8 million (8.1% of revenues) for the year ended December 31, 2000, an
increase of 5.9%. The increase was caused by the introduction of new costs as we
went through our initial public offering and continued the expansion of our
sales efforts and promotions.
Other Operating Expense. Other operating expense was $1.0 million for the year
ended December 31, 2001, which equaled the $1.0 million of other operating
expense for the year ended December 31, 2000. The other operating expense in
2001 relates to the charge relating to the write off of certain costs related to
the Midnight Warrior that could not be carried over to the conversion of the
Midnight Express. Other operating expense for the year ended December 31, 2000
primarily related to severance costs associated with a former employee and the
provision for doubtful trade receivables.
Interest Expense, Net. Net interest expense was $1.2 million for the year ended
December 31, 2001, compared to $3.8 million for the year ended December 31,
2000, an decrease of 69.2%. This decrease was achieved because we retired all
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outstanding debt in June 2001 with the proceeds of our initial public offering.
In addition, the remaining proceeds of our initial public offering led to $0.5
million in interest income.
Income Taxes. In connection with our initial public offering, we became subject
to corporate level taxation. As such, we recorded a one-time $2.6 million tax
charge based upon the cumulative book and tax basis differences at that time.
Additionally, we recorded a $0.8 million income tax provision, at a 35%
effective rate, on pretax earnings subsequent to our initial public offering. If
we had been subject to payment of income taxes for the entire periods, we would
have recorded an additional charge of $0.3 million for the year ended December
31, 2001, and a credit of $0.6 million for the year ended December 31, 2000.
Extraordinary Loss. In June 2001, we completed our initial public offering
resulting in the retirement of all outstanding debt balances. In connection with
this extinguishment of debt, we recognized a $0.5 million (net of taxes of $0.3
million) charge on the early extinguishment of debt (see Note 7 to the financial
statements).
Net Loss Attributable to Common Stockholders. Net loss to common stockholders
for the year ended December 31, 2001, was $0.7 million, compared with a net loss
of $1.6 million in 2000, including a $0.2 million and $0.3 million charge for
preferred dividends in 2001 and 2000, respectively.
LIQUIDITY AND CAPITAL RESOURCES
In June 2001, we completed an initial public offering of 5.0 million shares of
our common stock for gross proceeds of $80.0 million; net proceeds were $72.6
million after underwriting commission and discounts and expenses (the "Public
Offering"). We subsequently retired all debt, purchased the Midnight Rider, and
initiated the detailed engineering for the construction of the Midnight Warrior
(discussed below). We also used the proceeds from the Public Offering to
purchase the Midnight Express and commence the conversion of the vessel during
2002. Concurrent with the Public Offering, the predecessor company's $5.3
million of preferred membership units were exchanged for 828,333 shares of our
common stock.
In the year ended December 31, 2002, our operations used cash of $2.3 million as
compared to $2.4 million of cash generated during 2001. The proceeds from the
Public Offering and cash flow from operations funded the $24.2 million and $13.7
million used in investing activities related to the purchase of equipment in
2002 and 2001, respectively. Cash flow provided by financing activities was $2.3
million during 2002 as compared to $34.9 million in 2001. The 2002 cash flows
from financing consisted primarily of $4.3 million of net proceeds against our
receivable line of credit offset by $2.0 million of treasury stock purchases.
The Public Offering in 2001 greatly affected the cash flow from financing
activities in 2001 as described above and it also allowed us to retire all
outstanding debt and repurchase $2.2 million of treasury stock. Working capital
decreased from $30.6 million as of December 31, 2001 to $12.0 million as of
December 31, 2002 due primarily to the $17.8 million we expended during 2002
related to the conversion of the Midnight Express, an increase in accounts
payable-trade and the $4.3 million drawn against our receivable line of credit
facility.
Historically, our capital requirements have been primarily for the acquisition
and improvement of our vessels and other related equipment. We expect that as we
enter into the deepwater market our capital requirements will continue to be
primarily for the acquisition and improvement of our vessels. Capital
expenditures totaled $24.2 million for 2002, $13.7 million for 2001 and $2.5
million for 2000. The capital expenditures in 2002 primarily relate to the
deepwater expansion of our fleet funded with cash on hand. In prior years, the
capital expenditures represented the expansion of our fleet and were funded with
cash flow from operations, additional indebtedness and, most recently, proceeds
from the Public Offering. We expect to fund our cash requirements for any future
capital investments from cash on hand, cash flow from operations and by
utilizing our bank and debt facilities. We currently estimate capital
expenditures for 2003 to be approximately $71.9 million, primarily representing
the construction of, and the equipment and support facilities associated with,
the conversion of the Midnight Express. Included in this estimate are
approximately $2.9 million of
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improvements on the Midnight Wrangler and approximately $0.3 million for routine
capital and drydock inspections of our vessels to be incurred over this period.
Not included in this figure is the purchase price of the Midnight Wrangler of
$10.8 million, which will be financed by the seller as discussed below.
In July 2002, we entered into a $35.0 million bank facility (the "Bank
Facility") with Regions Bank consisting of a $25.0 million asset-based five-year
revolving credit facility and a $10.0 million accounts receivable-based working
capital facility. The interest on the Bank Facility is the London Interbank
Offered Rate (LIBOR) plus a range of 1.75% to 2.25%, depending upon the level of
the consolidated leverage ratio (as defined) measured on a quarterly basis.
Borrowings under the Bank Facility are secured by first preferred ship mortgage
liens on a portion of our fleet and a pledge of our accounts receivable. Amounts
outstanding under the accounts receivable-based working capital facility may not
exceed 85% of eligible trade accounts receivable. Under the terms of the Bank
Facility, we must maintain tangible net worth of at least $60.0 million, a
minimum debt service coverage ratio of at least 1.20 to 1, a consolidated
leverage ratio of no more than 2.00 to 1 and a consolidated current ratio of at
least 1.30 to 1. We had borrowed $4.3 million under the $10.0 million
accounts receivable-based working capital facility as of December 31, 2002. In
addition, we issued a $1.5 million standby letter of credit as security for the
charter payments due under the charter agreement for the Midnight Hunter against
the $10.0 million accounts receivable-based working capital facility and a $2.7
million standby letter of credit as security for payments related to a crane to
be constructed as part of the Midnight Express conversion against the $25.0
million asset-based five-year revolving credit facility.
In March 2003, we received commitment letters for a 15-month credit line to
finance the conversion of the Midnight Express (the "Finance Facility"),
however, the financing has not yet been finalized as it is contingent upon the
Shipyard contract becoming effective. The credit line will convert into a
three-year term loan facility upon completion of the conversion of the Midnight
Express. The Finance Facility commitment is equally provided by Regions Bank and
EDC ($30.0 million participation by each). As part of the terms and conditions
of the Finance Facility, Regions Bank will restructure the $25.0 million
asset-based five-year revolving credit facility discussed above and make this
part of the Finance Facility. We will continue to have available the $10.0
million accounts receivable-based working capital facility discussed above from
Regions Bank. In addition, the $2.7 million standby letter of credit as security
for payments related to a crane to be constructed as part of the Midnight
Express conversion will be transferred to the Finance Facility.
The interest rate for the construction financing will be based upon our
consolidated leverage ratio ranges from a LIBOR spread of 3.00% to 3.50% based
upon these levels. We will provide collateral in the form of the Midnight
Express as well as a first preferred ship mortgage on the Midnight Fox, Midnight
Star, Midnight Dancer, Midnight Carrier, Midnight Brave and Midnight Rider. We
will have to adhere to various conditions including maintaining tangible net
worth of at least $60.0 million, a minimum debt service coverage ratio of at
least 1.20 to 1, a consolidated leverage ratio of no more than 2.00 to 1 and a
consolidated current ratio of 1.30 to 1. We will not be allowed to incur
additional debt over $8.0 million without consent from Regions Bank. The actual
funding of the Finance Facility is to commence following effectiveness of the
Shipyard contract and once we have spent $30.0 million related to the conversion
of the Midnight Express. We had spent $19.5 million related to the conversion as
of December 31, 2002. We expect to have spent the $30.0 million required for the
funding of the Finance Facility by the end of the second quarter of 2003.
The term loan facility of the Finance Facility is a three-year debt structure
with a 10-year amortization payment schedule with semi-annual payments. The
pricing for this facility is 3.25% over LIBOR. Regions Bank and EDC would
require us to maintain the same collateral and covenants as included in the
construction financing depicted above.
Two conditions remain that the Shipyard must fulfill prior to the conversion
contract becoming effective. We have agreed to extend the date by which these
conditions must be met to April 2, 2003. If these conditions are not met, the
conversion contract will become null and void and we may have to submit the
project for re-bid. The delay resulting from re-bidding and re-awarding the
contract could result in substantial delay in delivery of the vessel and thus
would cause a delay in the implementation of our deepwater strategy and the
start of operations of the Midnight Express. Additionally, the cost of the
contract may increase and we would incur costs to move the vessel to another
shipyard. It is anticipated that the conversion will be performed by another
Canadian shipyard; however, our inability to complete the conversion in a
Canadian shipyard would result in the loss of the EDC portion of the financing
of the conversion. If we award the project to a shipyard that is not located in
Canada, we will have to secure additional financing for this project.
- 29 -
In March 2003, we finalized a $9.25 million, seven-year term loan with GE
Commercial Equipment Financing (GE). The loan is structured so that we receive
$8.0 million immediately and GE retains $1.25 million as a security deposit. The
interest rate on the term loan is the 30-day commercial paper rate plus 2.03%
and includes prepayment penalties of 2% for the first twelve months, 1% for the
second twelve months and 0% thereafter. The term loan is structured to have
monthly payments over seven years. The collateral for the loan is the Midnight
Eagle. We intend to utilize the proceeds from the loan to fund the improvements
to the Midnight Wrangler and a portion of the Midnight Express conversion costs.
In December 2002, we entered into a purchase agreement with Global Marine
Shipping Limited (Global Marine) for the purchase of the Wave Alert, to be
renamed the Midnight Wrangler, at a cost of approximately $10.8 million
(included in the Unconditional Purchase Obligations in the table below). We took
possession of the vessel in March 2003. The purchase of the vessel was financed
by Global Marine over a five-year period with monthly payments, including 7% per
annum interest, of approximately $0.2 million plus a $1.0 million payment at the
purchase in March 2003 and another $1.0 million payment at the end of the
five-year period. There is no debt recorded on our books as of December 31,
2002, as the purchase was contingent upon delivery of the vessel in March 2003.
The following table presents our long-term contractual obligations and the
related amounts due, in total and by period, as of December 31, 2002 (in
thousands):
Payments Due by Period
------------------------------------------------------------------------
Less Than After 5
Total 1 Year 1-3 Years 4-5 Years Years
------------ ------------ ------------ ------------ ------------
Long-Term Debt ......................... $ 60 $ 14 $ 22 $ 24 $--
Capital Lease Obligations .............. -- -- -- -- --
Operating Leases ....................... 9,007 3,879 5,022 106 --
Unconditional Purchase Obligations ..... 14,640 14,640 -- -- --
Other Long-Term Obligations ............ 29,892 29,892 -- -- --
------------ ------------ ------------ ------------ ------------
Total Contractual Cash Obligations ..... $ 53,599 $ 48,425 $ 5,044 $ 130 $--
============ ============ ============ ============ ============
Included in long-term debt is debt assumed by us as part of the purchase of a
leisure fishing vessel from an investment holding company wholly-owned by Mr.
Stockstill to be used for client and provider entertainment purposes. The total
cost of the vessel was approximately $0.1 million, of which $41,000 was paid
during 2002. The debt assumed will be paid in monthly installments over a
five-year period.
During 2002, we made payments of approximately $3.8 million for the operating
lease obligation relating to our deepwater technology vessel, the Midnight
Arrow, under a five-year charter agreement. We paid approximately $17.8 million
during 2002 in relation to the purchase price and conversion of the Midnight
Express bringing our total as of December 31, 2002 to $19.5 million. In
addition, we made cash payments of approximately $1.2 million during 2002
related to the three-year charter agreement for the Midnight Hunter, which was
terminated in January 2003.
Included in the operating leases are the monthly payments for certain facilities
used in the normal course of operations. However, the majority of the operating
leases obligation relates to our five-year charter agreement of the Midnight
Arrow. Included in the unconditional purchase obligations and other long-term
obligations is the purchase of the Midnight Wrangler as discussed above ($10.8
million) and the contracts with equipment suppliers related to the conversion of
the Midnight Express ($32.2 million) as well as equipment purchases for the
Midnight Wrangler ($1.5 million).
In August 2001, the Board of Directors approved the repurchase of up to $5.0
million of our outstanding common stock. Purchases will be made on a
discretionary basis in the open market or otherwise over a period of time as
determined by management subject to market conditions, applicable legal
requirements and other factors. During 2002, 300,168 shares were repurchased at
a total cost of approximately $2.0 million. There has been no repurchase of our
common stock since August 2002 and under current conditions and to support our
vessel expansion strategy we don't expect to repurchase shares in the near
future. As of March 25, 2003, 709,868 shares had been repurchased at a total
cost of $4.2 million.
- 30 -
Consistent with the focus towards investing in newer technology, including
deepwater capable assets such as the Midnight Express and the Midnight Wrangler,
four of the last five vessels added to our operations have been DP-2 deepwater
capable (Midnight Eagle, Midnight Arrow, Midnight Express and Midnight
Wrangler). Through December 31, 2002, we have expended approximately $48.9
million (in combined capital expenditures and operating lease payments) for
these vessels, with an additional estimated $90.8 million to be incurred in
associated construction costs, operating lease payments, purchase payments and
drydock expenses through 2005 (see Note 12 to the financial statements).
We believe that our existing cash and short-term investments and cash flow from
operations will be sufficient to meet our existing liquidity needs for the
operations of the business. We also believe that our existing cash and
short-term investments and the options offered by the Bank Facility, Finance
Facility and GE term loan, in addition to our cash flow from operations, will be
sufficient to complete our identified growth plans. If our plans or assumptions
change or prove to be inaccurate or if we make any additional acquisitions of
existing vessels or other businesses, we may need to raise additional capital.
We may not be able to raise these additional funds, or we may not be able to
raise such funds on favorable terms.
NEW ACCOUNTING PRONOUNCEMENTS
In July 2001, the Financial Accounting Standards Board (FASB) issued Statement
of Financial Accounting Standards (SFAS) No. 143, "Accounting for Asset
Retirement Obligations," effective for fiscal years beginning after June 15,
2002. This statement will require us to record the fair value of liabilities
related to future asset retirement obligations in the period the obligation is
incurred. We adopted SFAS No. 143 on January 1, 2003. Due to the nature of our
operations, the adoption of this statement did not impact our financial position
or results of operations.
In August 2001, the FASB issued SFAS No. 144, "Accounting for the Impairment or
Disposal of Long-Lived Assets," which supersedes SFAS No. 121, "Accounting for
the Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed
Of." The provisions of this statement revise current guidelines with respect to
the process of measuring impairment of long-lived assets. We adopted this
statement effective January 1, 2002; such adoption did not have a material
impact on our financial position or results of operations.
In April 2002, the FASB issued SFAS No. 145, "Rescission of FASB Statements No.
4, 44, and 64, Amendment of FASB Statement No. 13, and Technical Corrections,"
which revises current guidance with respect to gains and losses on early
extinguishment of debt. Under SFAS No. 145, gains and losses on early
extinguishment of debt are treated as extraordinary items unless they meet the
criteria for extraordinary treatment in Accounting Principles Board (APB)
Opinion No. 30. We adopted SFAS No. 145 effective January 1, 2003, and as a
result, will be required to reclassify the extraordinary losses on early
extinguishment of debt from prior periods in future filings as these amounts
will no longer qualify for extraordinary treatment under SFAS No. 145.
In July 2002, the FASB issued SFAS No. 146, "Accounting for Costs Associated
with Exit or Disposal Activities," which supersedes Emerging Issues Task Force
(EITF) Issue No. 94-3, "Liability Recognition for Certain Employee Termination
Benefits and Other Costs to Exit an Activity (including Certain Costs Incurred
in a Restructuring)." SFAS No. 146 requires the recognition of liabilities for
costs associated with an exit or disposal activity when those liabilities are
incurred rather than at the date of an entity's commitment to an exit or
disposal activity. This statement is effective for exit and disposal activities
that are initiated after December 31, 2002. We do not expect that SFAS No. 146
will have a material impact on our position or results of operations.
In December 2002, the FASB issued SFAS No. 148, "Accounting for Stock-Based
Compensation - Transition and Disclosure - an Amendment of SFAS No. 123," which
provides alternative methods of transition for a voluntary change to the fair
value-based method of accounting for stock-based employee compensation, and the
new standard, which is now effective, amends certain disclosure requirements. We
continue to apply APB No. 25, "Accounting for Stock Issued to Employees," and
related interpretations in accounting for our stock-based compensation;
therefore, the alternative methods of transition do not apply. We have adopted
the disclosure requirements of SFAS No. 148 (see Note 2 to the financial
statements.)
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In June 2001, the American Institute of Certified Public Accountants (AICPA)
issued an exposure draft of a proposed Statement of Position (SOP), "Accounting
for Certain Costs and Activities Related to Property, Plant, and Equipment."
This proposed SOP would change, among other things, the method by which
companies would account for normal, recurring or periodic repairs and
maintenance costs related to "in service" fixed assets. It would require that
these types of expenses be recognized when incurred rather than recognizing
expense for these costs while the asset is productive. The proposed SOP is still
under consideration, and uncertainties currently exist with respect to the
ultimate timing of its release and its final scope. We are assessing the impact
of the change should this SOP, or any portion of this SOP, be adopted and will
continue to monitor the progress of this proposed standard. If the portion of
this SOP relating to planned major maintenance activities is adopted, we would
be required to expense regulatory maintenance cost on our vessels as incurred
(currently capitalized and recognized as "drydocking cost amortization"), and
capitalized costs at the date of adoption would be charged to operations as a
cumulative effect of change in accounting principle.
CRITICAL ACCOUNTING POLICIES
Our discussion and analysis of our financial condition and results of operations
are based on our financial statements, which have been prepared in accordance
with accounting principles generally accepted in the United States. The
preparation of our financial statements requires us to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the
reporting period. There can be no assurance that actual results will not differ
from those estimates. We believe the following accounting policies, which are
described in Note 2 of the notes to our financial statements, represent our
critical accounting policies:
Revenue Recognition - We account for our contracts in progress using the
percentage-of-completion method, as our contracts contain multiple phases of
work. We believe that we have demonstrated the ability to produce reasonably
dependable estimates of the costs under such contracts, and that our business
has not been subject to the types of inherent risks that would raise questions
about the ability of either us or the customer to perform their obligations
under the contract or would make otherwise reasonably dependable contract
estimates doubtful.
Under this method, recognition of earnings on contracts in progress is
calculated based on the ratio of costs incurred as of the reporting date to
total expected costs to be incurred on each contract. Contract costs include all
direct material and labor costs and those indirect costs related to contract
performance, such as indirect labor, supplies, insurance and benefits. General
and administrative costs are charged to expense as incurred. Provisions for
estimated losses on uncompleted contracts are made in the period during which
such losses are first forecast.
Property and Equipment - Property and equipment are stated at cost less
applicable depreciation. Depreciation is calculated principally using the
straight-line method over the estimated useful lives of the various classes of
depreciable assets. Expenditures for maintenance and repairs are expensed as
incurred. Major expenditures for renewals and improvements that extend the
useful lives of existing assets, interest incurred during vessel construction,
and, when material, vessel construction related overhead and interest are
capitalized.
We assess the realizability of our long-term assets for impairment when events
or certain changes indicate the possibility that the carrying value of any such
asset may not be recoverable. We record impairment losses on long-term assets
used in operations when the carrying value of those assets is less than the
undiscounted cash flows estimated to be generated by those assets. The net
carrying value of assets that are considered to not be fully recoverable are
reduced to fair value. Our estimate of fair value represents our best estimate
based on industry trends and reference to market transactions and is subject to
variability. There have been no impairments in the accompanying financial
statements pursuant to SFAS No. 144 for the year ended December 31, 2002 and
SFAS No. 121 for previous years.
Deferred Drydocking Charges - We are obligated by regulation to periodically
incur refurbishment costs (known as "drydocking" costs) related to the
maintenance and operations of our marine vessels. We capitalize periodic
scheduled drydocking charges when incurred and amortize such costs on a
straight-line basis over a term that approximates the amount of time until the
next required drydocking refurbishment, generally two to three years. As of
December 31, 2002, we had approximately $2.6 million of deferred drydocking
charges, which will be amortized over future periods leading up to the next
required refurbishment. The estimated amortization periods used to recognize
such costs involve the use of management's judgment in deriving such estimates.
Income Taxes - Before our Public Offering in June 2001, we had elected to be
taxed as a flow-through entity under the Internal Revenue Code. Income taxes
related to our operations were recognized directly at the individual taxpayer
level. We recognized no federal or state income taxes for the period from 1997
to the Public Offering.
In connection with the Public Offering, we adopted SFAS No. 109, "Accounting for
Income Taxes." This statement requires the use of the liability method of
computing deferred income taxes. Under this method, deferred income taxes are
provided for the temporary differences between the financial reporting basis and
the tax basis of our 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 assessment of the realization of deferred tax assets, particularly
those related to tax operating loss carryforwards, involves the use of
management's judgment to determine whether it is more likely than not that we
will realize such tax benefits in the future.
- 32 -
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK
Interest Rate Risk. We are subject to market risk exposure related to changes in
interest rates on our Bank Facility (when drawn upon) and term loan with GE, and
potentially our Financing Facility. Interest on borrowings under the Bank
Facility accrue at a variable rate, using LIBOR plus a range of 1.75% to 2.25%,
depending upon the level of our consolidated leverage ratio (as defined)
measured on a quarterly basis. Our term loan with GE includes an interest rate
consisting of the 30-day commercial paper rate plus 2.03%. Under the potential
Financing Facility, the interest rate during the construction financing phase
will be based upon our consolidated leverage ratio and ranges from a LIBOR
spread of 3.00% to 3.50% based upon these levels. The term facility of the
Financing Facility is priced at 3.25% over LIBOR.
- 33 -
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
TORCH OFFSHORE, INC.
INDEX TO FINANCIAL STATEMENTS
PAGE
----
Reports of Independent Auditors ................................................................................... 35
Consolidated Balance Sheets as of December 31, 2002 and 2001 ...................................................... 37
Consolidated Statements of Operations for the Years Ended December 31, 2002, 2001 and 2000 ........................ 38
Consolidated Statements of Changes in Stockholders' Equity for the Years Ended December 31, 2002,
2001 and 2000 ..................................................................................................... 39
Consolidated Statements of Cash Flows for the Years Ended December 31, 2002, 2001 and 2000 ........................ 40
Notes to Consolidated Financial Statements ........................................................................ 41
- 34 -
REPORT OF INDEPENDENT AUDITORS
The Board of Directors
Torch Offshore, Inc.
We have audited the accompanying consolidated balance sheet of Torch Offshore,
Inc. as of December 31, 2002, and the related consolidated statements of
operations, changes in stockholders' equity, and cash flows for the year then
ended. These financial statements are the responsibility of the Company's
management. Our responsibility is to express an opinion on these financial
statements based on our audit. The consolidated financial statements of Torch
Offshore, Inc. as of December 31, 2001 and for the years ended December 31, 2001
and 2000 were audited by other auditors who have ceased operations and whose
report dated January 25, 2002 (except with respect to Note 16, as to which the
date was March 1, 2002), expressed an unqualified opinion on those statements.
We conducted our audit in accordance with auditing standards generally accepted
in the United States. Those standards require that we plan and perform the audit
to obtain reasonable assurance about whether the financial statements are free
of material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant estimates
made by management, as well as evaluating the overall financial statement
presentation. We believe that our audit provides a reasonable basis for our
opinion.
In our opinion, the 2002 financial statements referred to above present fairly,
in all material respects, the consolidated financial position of Torch Offshore,
Inc. as of December 31, 2002, and the consolidated results of its operations and
its cash flows for the year then ended in conformity with accounting principles
generally accepted in the United States.
ERNST & YOUNG LLP
New Orleans, Louisiana,
March 11, 2003
- 35 -
THIS IS A COPY OF THE AUDIT REPORT PREVIOUSLY ISSUED BY ARTHUR ANDERSEN LLP IN
CONNECTION WITH TORCH OFFSHORE, INC.'S FILING ON FORM 10-K FOR THE FISCAL YEAR
ENDED DECEMBER 31, 2001. THIS AUDIT REPORT HAS NOT BEEN REISSUED BY ARTHUR
ANDERSEN LLP IN CONNECTION WITH THIS FILING ON FORM 10-K FOR THE FISCAL YEAR
ENDED DECEMBER 31, 2002.
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors of Torch Offshore, Inc.:
We have audited the accompanying consolidated balance sheets of Torch Offshore,
Inc. (a Delaware corporation) and subsidiary as of December 31, 2001 and 2000,
and the related consolidated statements of operations, changes in stockholders'
equity, and cash flows for each of the three years in the period ended December
31, 2001. These financial statements are the responsibility of the Company's
management. Our responsibility is to express an opinion on these financial
statements based on our audits.
We conducted our audits in accordance with auditing standards generally accepted
in the United States. Those standards require that we plan and perform the audit
to obtain reasonable assurance about whether the financial statements are free
of material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant estimates
made by management, as well as evaluating the overall financial statement
presentation. We believe that our audits provide a reasonable basis for our
opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the consolidated financial position of Torch Offshore,
Inc. and subsidiary as of December 31, 2001 and 2000, and the consolidated
results of their operations and their cash flows for each of the three years in
the period ended December 31, 2001, in conformity with accounting principles
generally accepted in the United States.
ARTHUR ANDERSEN LLP
New Orleans, Louisiana,
January 25, 2002 (except with
respect to Note 16, as to which
the date is March 1, 2002)
- 36 -
TORCH OFFSHORE, INC.
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS)
DECEMBER 31,
2002 2001
----------- -----------
ASSETS
CURRENT ASSETS:
Cash and cash equivalents .................................................................. $ 327 $ 24,493
Accounts receivable --
Trade, less allowance for doubtful accounts of $1,132 and $218, respectively ............. 25,226 11,033
Other .................................................................................... 37 290
Costs and estimated earnings in excess of billings on uncompleted contracts ................ 2,036 1,600
Prepaid expenses and other ................................................................. 3,747 2,659
----------- -----------
Total current assets ................................................................. 31,373 40,075
PROPERTY AND EQUIPMENT, at cost, less accumulated depreciation ............................... 67,561 49,179
INVESTMENTS .................................................................................. 6 6
DEFERRED DRYDOCKING CHARGES, less accumulated amortization ................................... 2,831 3,245
OTHER ASSETS ................................................................................. 133 250
----------- -----------
Total assets ......................................................................... $ 101,904 $ 92,755
=========== ===========
LIABILITIES AND STOCKHOLDERS' EQUITY CURRENT LIABILITIES:
Accounts payable -- trade .................................................................. $ 7,677 $ 4,124
Accrued expenses ........................................................................... 3,696 2,909
Accrued payroll and related taxes .......................................................... 857 791
Financed insurance premiums ................................................................ 2,553 1,075
Deferred income taxes ...................................................................... 287 535
Current portion of long-term debt .......................................................... 14 --
Receivable line of credit .................................................................. 4,271 --
----------- -----------
Total current liabilities ........................................................... 19,355 9,434
DEFERRED INCOME TAXES ........................................................................ 2,636 2,280
LONG-TERM DEBT, less current portion ......................................................... 46 --
COMMITMENTS AND CONTINGENCIES (Note 12)
STOCKHOLDERS' EQUITY:
Preferred stock, $0.01 par value; 10,000 authorized shares; none issued and outstanding .... -- --
Common stock, $0.01 par value; 100,000 authorized shares; 13,399 shares in 2002 and
13,366 shares in 2001 issued and outstanding ............................................... 134 134
Additional paid-in-capital ................................................................. 85,638 85,199
Deferred compensation ...................................................................... (492) (473)
Treasury stock, at cost, 710 shares in 2002 and 410 shares in 2001 ......................... (4,234) (2,245)
Retained earnings (deficit) ................................................................ (1,179) (1,574)
----------- -----------
Total stockholders' equity ........................................................... 79,867 81,041
----------- -----------
Total liabilities and stockholders' equity ........................................... $ 101,904 $ 92,755
=========== ===========
The accompanying notes are an integral part of these consolidated
financial statements.
- 37 -
TORCH OFFSHORE, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
(IN THOUSANDS, EXCEPT PER SHARE DATA)
YEARS ENDED DECEMBER 31,
2002 2001 2000
-------- -------- --------
Revenues ....................................................................... $ 67,990 $ 59,052 $ 46,205
Cost of revenues:
Cost of sales .................................................................. 53,341 43,190 34,011
Depreciation and amortization .................................................. 7,540 6,376 4,941
General and administrative expenses ............................................ 4,767 3,982 3,759
Other operating expense (Notes 2, 6 and 11) .................................... 1,966 950 954
-------- -------- --------
Total cost of revenues ........................................................ 67,614 54,498 43,665
-------- -------- --------
Operating income ............................................................... 376 4,554 2,540
-------- -------- --------
Other income (expense):
Interest expense ............................................................... -- (1,642) (3,814)
Interest income ................................................................ 232 468 1
-------- -------- --------
Total other income (expense) .................................................. 232 (1,174) (3,813)
-------- -------- --------
Income (loss) before income taxes and extraordinary item ....................... 608 3,380 (1,273)
Income tax expense ............................................................. (213) (3,433) --
-------- -------- --------
Net income (loss) before extraordinary item .................................... 395 (53) (1,273)
Extraordinary loss on early extinguishment of debt, net of taxes of $268 in
2001 (Notes 2 and 7) ......................................................... -- (498) --
-------- -------- --------
Net income (loss) .............................................................. 395 (551) (1,273)
Preferred unit dividends and accretion ......................................... -- (190) (305)
-------- -------- --------
Net income (loss) attributable to common stockholders .......................... $ 395 $ (741) $ (1,578)
======== ======== ========
Basic and Diluted income (loss) per common share (Note 2):
Weighted average shares of common stock outstanding - Basic .................... 12,692 10,845 7,505
======== ======== ========
Weighted average shares of common stock outstanding - Diluted .................. 12,695 10,845 7,505
======== ======== ========
Net income (loss) per share before extraordinary item - Basic and Diluted ...... $ 0.03 $ (0.02) $ (0.21)
Extraordinary loss ............................................................. -- (0.05) --
-------- -------- --------
Net income (loss) per share - Basic and Diluted ................................ $ 0.03 $ (0.07) $ (0.21)
======== ======== ========
The accompanying notes are an integral part of these consolidated
financial statements.
- 38 -
TORCH OFFSHORE, INC.
CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY
(IN THOUSANDS)
COMMON STOCK
OUTSTANDING ADDITIONAL DEFERRED TREASURY STOCK RETAINED TOTAL
------------------- PAID-IN COMPEN- ------------------- EARNINGS STOCKHOLDER'S
SHARES AMOUNT CAPITAL SATION SHARES AMOUNT (DEFICIT) EQUITY
-------- -------- ---------- -------- -------- -------- -------- -------------
BALANCE, January 1, 2000 .............. 7,505 $ -- $ 239 $ -- -- $ -- $ 7,650 $ 7,889
Net loss ............................ -- -- -- -- -- -- (1,273) (1,273)
Preferred unit dividends and
accretion .......................... -- -- -- -- -- -- (305) (305)
-------- -------- ---------- -------- -------- -------- -------- -------------
BALANCE, December 31, 2000 ............ 7,505 -- 239 -- -- -- 6,072 6,311
Net income prior to Public Offering.. -- -- -- -- -- -- 1,023 1,023
Preferred unit dividends and
accretion .......................... -- -- -- -- -- -- (190) (190)
Exchange of membership interests .... 828 83 11,535 -- -- -- (6,905) 4,713
-------- -------- ---------- -------- -------- -------- -------- -------------
BALANCE, Prior to Public Offering ..... 8,333 83 11,774 -- -- -- -- 11,857
Issuance of public shares, net ...... 5,000 50 72,900 -- -- -- -- 72,950
Issuance of restricted shares ....... 33 1 525 (526) -- -- -- --
Deferred compensation earned ........ -- -- -- 53 -- -- -- 53
Repurchases of common stock ......... -- -- -- -- 410 (2,245) -- (2,245)
Net loss after Public Offering ...... -- -- -- -- -- (1,574) (1,574)
-------- -------- ---------- -------- -------- -------- -------- -------------
BALANCE, December 31, 2001 ............ 13,366 134 85,199 (473) 410 (2,245) (1,574) 81,041
Issuance of restricted shares ....... 33 -- 196 (141) -- -- -- 55
Revision to Public offering cost tax
benefit ........................... -- -- 243 -- -- -- -- 243
Deferred compensation earned ........ -- -- -- 122 -- -- -- 122
Repurchases of common stock ......... -- -- -- -- 300 (1,989) -- (1,989)
Net income .......................... -- -- -- -- -- -- 395 395
-------- -------- ---------- -------- -------- -------- -------- -------------
BALANCE, December 31, 2002 ............ 13,399 $ 134 $ 85,638 $ (492) 710 $ (4,234) $ (1,179) $ 79,867
======== ======== ========== ======== ======== ======== ======== =============
The accompanying notes are an integral part of these consolidated
financial statements.
- 39 -
TORCH OFFSHORE, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
YEARS ENDED DECEMBER 31,
2002 2001 2000
--------- --------- ---------
CASH FLOWS PROVIDED BY (USED IN) OPERATING ACTIVITIES:
Net income (loss) ............................................................... $ 395 $ (551) $ (1,273)
Depreciation and amortization ................................................. 7,540 6,376 4,941
Write off of vessel costs ..................................................... 1,052 950 --
Deferred income tax provision ................................................. 213 4,241 --
Provision for doubtful accounts ............................................... 914 -- 475
Extraordinary loss on extinguishment of debt .................................. -- 498 --
Severance and reorganizational costs, net unpaid (paid) ....................... -- (1,764) 300
Deferred drydocking costs incurred ............................................ (2,332) (1,253) (2,171)
(Increase) decrease in working capital:
Accounts receivable ........................................................... (14,854) (1,457) (5,643)
Costs and estimated earnings in excess of billings on uncompleted contracts ... (436) (1,077) 369
Prepaid expenses, net of financed portion ..................................... 390 (911) (159)
Accounts payable -- trade ..................................................... 3,553 (3,685) 3,445
Accrued payroll and related taxes ............................................. 66 331 127
Accrued expenses and other .................................................... 1,220 721 1,335
--------- --------- ---------
Net cash provided by (used in) operating activities ............................. (2,279) 2,419 1,746
--------- --------- ---------
CASH FLOWS USED IN INVESTING ACTIVITIES:
Purchases of property and equipment ........................................... (24,229) (13,741) (2,538)
--------- --------- ---------
Net cash used in investing activities ........................................... (24,229) (13,741) (2,538)
--------- --------- ---------
CASH FLOWS PROVIDED BY FINANCING ACTIVITIES:
Proceeds from initial public offering ......................................... -- 80,000 --
Payments of initial public offering costs ..................................... -- (7,400) --
Net proceeds from (payments on) receivable line of credit ..................... 4,271 (3,436) 108
Proceeds from long-term debt .................................................. 60 -- --
Payments on long-term debt .................................................... -- (30,821) (4,455)
Proceeds from issuance of preferred units ..................................... -- -- 5,300
Preferred unit issuance costs ................................................. -- -- (490)
Premium/cost of debt extinguishment ........................................... -- (766) --
Treasury stock purchases ...................................................... (1,989) (2,245) --
Stockholder distributions ..................................................... -- (403) --
--------- --------- ---------
Net cash provided by financing activities ....................................... 2,342 34,929 463
--------- --------- ---------
Net increase (decrease) in cash ................................................. (24,166) 23,607 (329)
Cash at beginning of year ....................................................... 24,493 886 1,215
--------- --------- ---------
Cash at end of year ............................................................. $ 327 $ 24,493 $ 886
========= ========= =========
Interest paid (net of amounts capitalized) ...................................... $ -- $ 1,943 $ 3,863
========= ========= =========
Income taxes paid ............................................................... $ -- $ -- $ --
========= ========= =========
The accompanying notes are an integral part of these consolidated
financial statements.
- 40 -
TORCH OFFSHORE, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. NATURE OF BUSINESS:
Torch Offshore, Inc., a Delaware corporation, and its subsidiaries
(collectively, the "Company") provide integrated pipeline installation, subsea
construction and support services to the offshore oil and natural gas industry
primarily in the United States Gulf of Mexico (the "Gulf of Mexico"). The
Company's focus has been providing services primarily for oil and natural gas
production in water depths of 20 to 300 feet in the Gulf of Mexico (the
"Shelf"). Over the past few years, the Company has expanded its operations,
fleet capabilities and management expertise to enable it to provide deeper water
services analogous to those services it provides on the Shelf.
Torch, Inc. (Torch), the predecessor in interest to Torch Offshore, L.L.C., was
incorporated in Louisiana in 1978. Torch is owned by Lyle G. Stockstill and Lana
J. Hingle Stockstill (Mr. and Mrs. Stockstill), the founders of the Company. In
May 2000, Torch Offshore, L.L.C. was formed to hold substantially all of the
assets and liabilities of Torch. In January 2001, the Board of Directors of
Torch formed Torch Offshore, Inc., which filed a registration statement on Form
S-1 with the Securities and Exchange Commission (the "SEC") to register and sell
common stock of the Company. In June 2001, the Company completed its initial
public offering (the "Public Offering") of 5.0 million shares of its common
stock at $16.00 per share, raising gross proceeds of $80.0 million; net proceeds
were $72.6 million after underwriting commission and discounts and expenses
totaling $7.4 million.
In connection with the Public Offering, all membership interests in Torch
Offshore, L.L.C. (including preferred unit interests) were contributed to the
Company in exchange for common shares of the Company. In the aggregate, Mr. and
Mrs. Stockstill presently own a majority of the Company through their ownership
of Torch. For financial reporting purposes, these transactions were considered a
recapitalization, and as such, all historical share data included in the
accompanying financial statements has been restated (see Note 3).
In 2002, the Company established Torch Express, L.L.C., a wholly-owned
subsidiary, for the purpose of converting the Midnight Express into a
dynamically positioned (DP-2) offshore construction vessel capable of working in
deepwater areas worldwide (see Notes 6 and 7).
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:
The accounting and reporting policies of the Company conform with accounting
principles generally accepted in the United States. A summary of significant
accounting policies follows:
Principles of Consolidation - The consolidated financial statements include the
accounts of Torch Offshore, Inc. and its wholly-owned subsidiaries, Torch
Offshore, L.L.C. and Torch Express, L.L.C. All significant intercompany balances
and transactions have been eliminated in consolidation.
Use of Estimates - The presentation of financial statements in conformity with
accounting principles generally accepted in the United States requires
management to make estimates and assumptions that affect the reported amounts of
assets and liabilities and disclosure of contingent assets and liabilities at
the date of the financial statements and the reported amounts of revenues and
expenses during the reporting period. Actual results could differ from those
estimates.
Cash and Cash Equivalents - The Company considers all highly liquid investments
with an original maturity of three months or less to be cash equivalents. The
carrying amount of these instruments approximates fair value because of their
short maturity.
Allowance for Doubtful Accounts - The Company provides allowances for doubtful
accounts based on historical experience and a review of the current status of
existing accounts receivable balances at the end of each reporting period.
Provisions for doubtful accounts are recorded as charges to other operating
expense. Activity within the allowance for doubtful accounts follows (in
thousands):
- 41 -
2002 2001 2000
-------- -------- --------
Beginning balance ........ $ 218 $ 607 $ 132
Provision ................ 914 -- 475
Deductions ............... -- (389) --
-------- -------- --------
Ending Balance ........... $ 1,132 $ 218 $ 607
======== ======== ========
Property and Equipment - Property and equipment are stated at cost less
applicable depreciation. Depreciation is calculated principally using the
straight-line method over the estimated useful lives of the various classes of
depreciable assets. Expenditures for maintenance and repairs are expensed as
incurred. Major expenditures for renewals and improvements that extend the
useful lives of existing assets, interest incurred during vessel construction,
and, when material, vessel construction related overhead are capitalized. For
the year ended December 31, 2002, interest costs of $0.1 million were
capitalized as they were related to the construction of the Midnight Express
(see Note 6). There was no interest capitalized for the years ended December 31,
2001 or 2000.
The Company periodically assesses the realizability of its long-term assets
pursuant to Statement of Financial Accounting Standards (SFAS) No. 144,
"Accounting for the Impairment or Disposal of Long-Lived Assets." SFAS No. 144,
which superseded SFAS No. 121, "Accounting for the Impairment of Long-Lived
Assets and for Long-Lived Assets to Be Disposed Of," revised the guidance with
respect to the process for measuring impairment of long-lived assets. An asset
impairment is recognized if the future undiscounted cash flows of the asset are
less than the carrying value of the asset. The impairment loss to be recognized
is measured as the amount by which the carrying value of the asset exceeds its
fair value. The Company adopted this statement effective January 1, 2002. No
impairment charges were recorded for the years ending December 31, 2002, 2001 or
2000.
Investments - Long-term investments represent net remaining deposits made by the
Company under the U.S. Government sponsored Merchant Marine Capital Construction
Fund (CCF) program. The CCF program allows the Company to set aside and use its
own funds for the purpose of funding current or future construction of qualified
marine vessels to be used in the Company's operations, while allowing the
Company to receive accelerated tax deductions equal to the amount originally
deposited.
These investments are comprised of deposits in an interest bearing, money-market
account, with interest income recorded as earned. Although these investments are
short-term in nature, similar to cash and cash equivalents, because of the
purpose of the deposits the Company has reflected these as a long-term asset.
There are no restrictions on these investments; however, unqualified withdrawals
from this program would be subject to income taxes in the period withdrawn. The
fair value of investments approximated carrying value as of December 31, 2002
and 2001.
Deferred Drydocking Charges - The Company is obligated by regulation to
periodically incur refurbishment costs (known as "drydocking" costs) related to
the maintenance and operation of its marine vessels. The Company capitalizes
periodic scheduled drydocking charges when incurred and amortizes such costs on
a straight-line basis over a term that approximates the amount of time until the
next required drydocking refurbishment, generally two to three years.
Amortization expense for deferred drydocking charges totaled $2,745,000 in 2002,
$2,562,000 in 2001 and $1,485,000 in 2000.
Revenue Recognition - The Company accounts for its contracts in progress using
the percentage-of-completion method, as its contracts contain multiple phases of
work. The Company believes that it has demonstrated the ability to produce
reasonably dependable estimates of the costs under such contracts, and that its
business has not been subject to the types of inherent risks that would raise
questions about the ability of either the Company or the customer to perform
their obligations under the contract or would make otherwise reasonably
dependable contract estimates doubtful.
Under this method, recognition of earnings on contracts in progress is
calculated based on the ratio of costs incurred as of the reporting date to
total expected costs to be incurred on each contract.
- 42 -
Contract costs include all direct material and labor costs and those indirect
costs related to contract performance, such as indirect labor, supplies,
insurance and benefits. General and administrative costs are charged to expense
as incurred. Provisions for estimated losses on uncompleted contracts are made
in the period during which such losses are first forecast.
The asset caption "Costs and Estimated Earnings in Excess of Billings on
Uncompleted Contracts" represents revenues recognized in excess of amounts
billed.
Income Taxes - Prior to the Public Offering in June 2001, the Company had
elected to be taxed as a flow-through entity under the Internal Revenue Code.
Income taxes related to the operations of the Company were recognized directly
at the individual taxpayer level. Therefore, the Company recognized no federal
or state income tax for the period from 1997 until the Public Offering.
In connection with the Public Offering, the Company adopted SFAS No. 109,
"Accounting for Income Taxes." This statement requires the use of the liability
method of computing deferred income taxes. Under this method, deferred income
taxes are provided for the temporary differences between the financial reporting
basis and the tax basis of the Company's 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.
Segments - The Company's business is considered a single operation with no
separately reportable segments in accordance with SFAS No. 131, "Disclosures
About Segments of an Enterprise and Related Information." The Company has
domestic operations in one industry segment, the marine construction service
industry.
Earnings Per Share - The Company follows SFAS No. 128, "Earnings per Share."
Basic earnings per share is calculated by dividing income attributable to common
stockholders by the weighted-average number of common shares outstanding for the
applicable period, without adjustment for potential common shares outstanding in
the form of options, warrants, convertible securities or contingent stock
agreements. For the calculation of diluted earnings per share, the number of
common shares outstanding are increased (if deemed dilutive) by the number of
additional common shares that would have been outstanding if the dilutive
potential common shares had been issued, determined using the treasury stock
method where appropriate.
NET
(in thousands, except per share data) INCOME/ PER SHARE
(LOSS) SHARES AMOUNT
------------ ------------ ------------
2002
Basic Earnings Per Share:
Earnings attributable to common stockholders ........ $ 395 12,692 $ 0.03
============
Impact of stock options and restricted stock ........ -- 3
------------ ------------
Diluted Earnings Per Share ............................ $ 395 12,695 $ 0.03
============ ============ ============
2001
Basic Loss Per Share:
Loss attributable to common stockholders ............ $ (741) 10,845 $ (0.07)
============
Impact of stock options and restricted stock
(none due to anti-dilutive effect) ................. -- --
------------ ------------
Diluted Loss Per Share ................................ $ (741) 10,845 $ (0.07)
============ ============ ============
2000
Basic Loss Per Share:
Loss attributable to common stockholders ............ $ (1,578) 7,505 $ (0.21)
============
Impact of stock options and restricted stock
(none due to anti-dilutive effect) ................. -- --
------------ ------------
Diluted Loss Per Share ................................ $ (1,578) 7,505 $ (0.21)
============ ============ ============
- 43 -
Common stock equivalents (related to stock options) excluded from the
calculation of the diluted earnings per share, because they were anti-dilutive,
were approximately 351,000 shares for 2002, 224,000 shares for 2001 and 363,500
shares for 2000. None of the outstanding shares of convertible preferred stock
were considered in the calculation of the diluted loss per share for 2000
because of their anti-dilutive effect.
Derivative Financial Instruments - Effective January 1, 1999, the Company
adopted SFAS No. 133, "Accounting for Derivative Instruments and Hedging
Activities," as amended, which established accounting and reporting standards
requiring that every derivative instrument (including certain derivative
instruments embedded in other contracts) be recorded in the balance sheet as
either an asset or liability measured at its fair value. SFAS No. 133 requires
that changes in a derivative's fair value be recognized currently in earnings
unless specific hedge accounting criteria are met. Special accounting for
qualifying hedges allows a derivative's gains and losses to be recorded through
equity via other comprehensive income, and requires that a company must formally
document, designate and assess the effectiveness of transactions that receive
hedge accounting. The Company has not historically entered into these derivative
instruments, nor were there any contracts existing as of December 31, 2002 or
2001; thus, the adoption of SFAS No. 133 did not have an impact on its financial
position or results of operations.
Stock-Based Compensation - The Company accounts for its stock-based compensation
in relation to the 2001 Long-Term Incentive Plan in accordance with Accounting
Principles Board Opinion (APB) No. 25, "Accounting for Stock Issued to
Employees." However, SFAS No. 123, "Accounting for Stock-Based Compensation,"
and SFAS No. 148, "Accounting for Stock-Based Compensation - Transition and
Disclosure - An Amendment of SFAS No. 123", permit the intrinsic value-based
method prescribed by APB No. 25, but require additional disclosures, including
pro forma calculations of earnings and net earnings per share as if the fair-
value method of accounting prescribed by SFAS No. 123 had been applied. If
compensation expense had been determined using the fair-value method in SFAS No.
123, the Company's net income (loss) and earnings (loss) per share would have
been as shown in the pro forma amounts below:
(in thousands, except per share data) 2002 2001 2000
----------- ----------- -----------
Net income (loss) attributable to common stockholders:
As reported ............................................................. $ 395 $ (741) $ (1,578)
Pro forma ............................................................... $ 64 $ (924) $ (1,723)
Basic earnings (loss) per share:
As reported ............................................................. $ 0.03 $ (0.07) $ (0.21)
Pro forma ............................................................... $ 0.01 $ (0.09) $ (0.23)
Diluted earnings (loss) per share:
As reported ............................................................. $ 0.03 $ (0.07) $ (0.21)
Pro forma ............................................................... $ 0.01 $ (0.09) $ (0.23)
Average fair value of grants during the year ............................ $ 5.31 $ 10.98 --
Black-Scholes option pricing model assumptions:
Risk free interest rate ................................................. 4.78% 4.88% --
Expected life (years) ................................................... 7.0 5.0 --
Volatility .............................................................. 58.19% 76.40% --
Dividend yield .......................................................... -- -- --
Stock-based employee compensation cost, net of tax, included in net
income (loss) as reported ............................................... $ 122 $ 53 $ --
Stock-based employee compensation cost, net of tax, that would have
been included in net income if the fair-value based method had been
applied ................................................................. $ 453 $ 236 $ 145
- 44 -
New Accounting Standards - In July 2001, the Financial Accounting Standards
Board (FASB) issued SFAS No. 143, "Accounting for Asset Retirement Obligations,"
effective for fiscal years beginning after June 15, 2002. This statement will
require the Company to record the fair value of liabilities related to future
asset retirement obligations in the period the obligation is incurred. The
Company adopted SFAS No. 143 on January 1, 2003. Due to the nature of the
Company's operations, the adoption of this statement did not impact the
Company's financial position or results of operations.
In April 2002, the FASB issued SFAS No. 145, "Rescission of FASB Statements No.
4, 44, and 64, Amendment of FASB Statement No. 13, and Technical Corrections,"
which revises current guidance with respect to gains and losses on early
extinguishment of debt. Under SFAS No. 145, gains and losses on early
extinguishment of debt are treated as extraordinary items unless they meet the
criteria for extraordinary treatment in APB No. 30. The Company adopted SFAS No.
145 effective January 1, 2003, and as a result, will be required to reclassify
the extraordinary losses on early extinguishment of debt from prior periods in
future filings as these amounts will no longer qualify for extraordinary
treatment under SFAS No. 145.
In July 2002, the FASB issued SFAS No. 146, "Accounting for Costs Associated
with Exit or Disposal Activities," which supersedes Emerging Issues Task Force
(EITF) Issue No. 94-3, "Liability Recognition for Certain Employee Termination
Benefits and Other Costs to Exit an Activity (including Certain Costs Incurred
in a Restructuring)." SFAS No. 146 requires the recognition of liabilities for
costs associated with an exit or disposal activity when those liabilities are
incurred rather than at the date of an entity's commitment to an exit or
disposal activity. This statement is effective for exit and disposal activities
that are initiated after December 31, 2002. The Company does not expect that
SFAS No. 146 will have a material impact on the Company's financial position or
results of operations.
In December 2002, the FASB issued SFAS No. 148, which provides alternative
methods of transition for a voluntary change to the fair-value based method of
accounting for stock-based employee compensation, and the new standard, which is
now effective, amends certain disclosure requirements. The Company continues to
apply APB No. 25, "Accounting for Stock Issued to Employees," and related
interpretations in accounting for its stock-based compensation; therefore, the
alternative methods of transition do not apply. The Company has adopted the
disclosure requirements of SFAS No. 148 (see "Stock-Based Compensation" above).
In June 2001, the American Institute of Certified Public Accountants (AICPA)
issued an exposure draft of a proposed Statement of Position (SOP), "Accounting
for Certain Costs and Activities Related to Property, Plant, and Equipment."
This proposed SOP would change, among other things, the method by which
companies would account for normal, recurring or periodic repairs and
maintenance costs related to "in service" fixed assets. It would require that
these types of expenses be recognized when incurred rather than recognizing
expense for these costs while the asset is productive. The proposed SOP is still
under construction, and uncertainties currently exist with respect to the
ultimate timing of its release and its final scope. The Company is assessing the
impact of the change should this SOP, or any portion of this SOP, be adopted and
continues to monitor the progress of this proposed standard. If the portion of
this SOP relating to planned major maintenance activities is adopted, the
Company would be required to expense regulatory maintenance cost on its vessels
as incurred (currently capitalized and recognized as "drydocking cost
amortization"), and capitalized costs at the date of adoption would be charged
to operations as a cumulative effect of change in accounting principle.
3. RECAPITALIZATION:
In May 2000, Torch transferred, at historical cost, substantially all assets,
liabilities and operations to a newly formed subsidiary, Torch Offshore, L.L.C.,
in exchange for common membership units of Torch Offshore, L.L.C. Immediately
following the transfer, Torch Offshore, L.L.C. issued 7% Convertible Preferred
Membership Units (Preferred Units) to an outside investor for $5.3 million. The
Preferred Units were converted to 828,333 shares of common stock of the Company
just prior to the Public Offering.
4. CONCENTRATIONS OF CREDIT RISK:
Financial instruments that potentially subject the Company to concentrations of
credit risk consist principally of cash deposits and trade accounts receivable.
The Company at times has cash on deposit at financial institutions that is in
excess of federally insured limits. Also, the Company's trade receivables are
generally unsecured except for lien rights, and are
- 45 -
due from customers, substantially all of whom are engaged in the production and
development of oil and natural gas located in the Gulf of Mexico.
5. COSTS AND ESTIMATED EARNINGS IN EXCESS OF BILLINGS ON UNCOMPLETED CONTRACTS:
Costs and estimated earnings in excess of billings on uncompleted contracts
consisted of the following (in thousands):
DECEMBER 31,
2002 2001
--------- ---------
Costs incurred .......... $ 4,287 $ 2,999
Estimated earnings ...... 2,809 346
--------- ---------
7,096 3,345
Less billings ........... 5,060 1,745
--------- ---------
$ 2,036 $ 1,600
========= =========
6. PROPERTY AND EQUIPMENT:
The major classifications and estimated useful lives of property and equipment
follow (in thousands, except useful life data):
ESTIMATED
USEFUL
DECEMBER 31, LIVES
2002 2001 (IN YEARS)
----------- ------------- ------------
Leasehold improvements ............ $ 398 $ 247 5
Vessels ........................... 63,359 61,343 7-20
Vessels under construction ........ 21,838 1,741 --
Furniture and fixtures ............ 646 523 2-5
Equipment ......................... 1,289 633 5
Automobiles and trucks ............ 368 344 3-5
----------- -------------
87,898 64,831
Less accumulated depreciation ..... (20,337) (15,652)
----------- -------------
$ 67,561 $ 49,179
=========== =============
Depreciation expense totaled $4,795,000 for 2002, $3,814,000 for 2001 and
$3,456,000 for 2000. During the year ended December 31, 2002, $136,000 of
interest related to vessel construction was capitalized (see Note 2).
In January 2002, the Company entered into an agreement for the purchase of the
Smit Express, a 520-foot vessel, from Smit International for $9.75 million. The
Company is converting the vessel into a DP-2 offshore construction vessel and
has renamed it the Midnight Express. The conversion is estimated to cost between
$80.0 million and $90.0 million. Full integration of the equipment, the pipelay
system and the vessel, followed by sea trials, is scheduled for early 2004 (see
Note 7).
Formerly included in "Vessels Under Construction" were the engineering, design,
legal and other costs associated with the Company's efforts to pursue
construction of the Midnight Warrior. However, the Company tabled the
construction of this vessel with the acquisition of the Midnight Express. The
Midnight Express will be similar to the proposed Midnight Warrior in various
aspects, therefore many of the costs incurred to pursue construction of the
Midnight Warrior are being utilized in the conversion of the Midnight Express.
The Company reviewed the costs included in "Vessels Under Construction" at
December 31, 2001 and recorded a charge of $950,000 in 2001 for certain
identifiable costs that were deemed to have no value to the conversion of the
Midnight Express. Additional charges of $185,000 were recognized in 2002 related
to the Company's change in pursuit from the Midnight Warrior project to the
Midnight Express project.
- 46 -
In December 2002, the Company entered into an agreement for the purchase of the
Wave Alert, a 340-foot cable-laying DP-2 vessel from Global Marine Shipping
Limited (Global Marine). The Company took possession of the vessel in March
2003, at which time it was renamed the Midnight Wrangler. The vessel was
delivered without cable laying equipment and directly from its required drydock.
A 125-ton crane, a modular pipelay system and additional accommodations will be
installed on the vessel by the Company before it joins the active fleet during
the second quarter of 2003 (see Note 7).
In June 2001, the Company purchased an existing pipelay/bury barge, the BH-400
(renamed the Midnight Rider), for $9.5 million. This barge completed a required
drydocking and was placed into service in late 2001.
7. LONG-TERM DEBT:
In June 2001, the Company repaid all debt with proceeds from the Public
Offering. The Company had re-financed its fleet-related borrowings in 1999 with
a six-year, $33.0 million, 10.56% fixed interest rate installment loan. This
repayment of debt resulted in the Company incurring an extraordinary loss on the
early retirement of debt of $498,000 (net of taxes of $268,000).
In July 2002, the Company entered into a $35.0 million bank facility (the "Bank
Facility") consisting of a $25.0 million asset-based five-year revolving credit
facility and a $10.0 million accounts receivable-based working capital facility
with Regions Bank. The interest on the Bank Facility is the London Interbank
Offered Rate (LIBOR) plus a range of 1.75% to 2.25%, depending on the level of
the consolidated leverage ratio (as defined) measured on a quarterly basis.
Borrowings under the Bank Facility are secured by first preferred ship mortgage
liens on a portion of the Company's fleet and a pledge of the Company's accounts
receivable. Amounts outstanding under the accounts receivable-based working
capital facility may not exceed 85% of eligible trade accounts receivable. Under
the terms of the Bank Facility, the Company must maintain tangible net worth
of at least $60.0 million, a minimum debt service coverage ratio of at least
1.20 to 1, a consolidated leverage ratio of no more than 2.00 to 1 and a
consolidated current ratio of at least 1.30 to 1. The Company had borrowed $4.3
million under the $10.0 million accounts receivable-based working capital
facility as of December 31, 2002. In addition, the Company issued a $1.5 million
standby letter of credit as security for the charter payments due under the
charter agreement for the Midnight Hunter against the $10.0 million
accounts receivable-based working capital facility and a $2.7 million standby
letter of credit as security for payments related to a crane to be constructed
as part of the Midnight Express conversion against the $25.0 million asset-based
five-year revolving credit facility.
In March 2003, the Company received commitment letters for a 15-month credit
line to finance the conversion of the Midnight Express (the "Finance Facility"),
however, the financing has not yet been finalized as it is contingent upon the
contract with Davie Maritime Inc. of Quebec, Canada (the "Shipyard") becoming
effective. The credit line will convert into a three-year term loan facility
upon completion of the conversion of the Midnight Express. The Finance Facility
commitment is equally provided by Regions Bank and Export Development Canada
(EDC) ($30.0 million participation by each). As part of the terms and conditions
of the Finance Facility, Regions Bank will restructure the $25.0 million
asset-based five-year revolving credit facility discussed above and make this
part of the Finance Facility. The Company will continue to have available the
$10.0 million accounts receivable-based working capital facility discussed above
from Regions Bank. In addition, the $2.7 million standby letter of credit as
security for payments related to a crane to be constructed as part of the
Midnight Express conversion will be transferred to the Finance Facility.
The interest rate for the construction financing will be based upon the
consolidated leverage ratio of the Company and ranges from a LIBOR spread of
3.00% to 3.50% based upon these levels. The Company will provide collateral in
the form of the Midnight Express as well as a first preferred ship mortgage on
the Midnight Fox, Midnight Star, Midnight Dancer, Midnight Carrier, Midnight
Brave and Midnight Rider. The Company will have to adhere to various conditions
including maintaining a tangible net worth of at least $60.0 million, a minimum
debt service coverage ratio of at least 1.20 to 1, a consolidated leverage ratio
of no more than 2.00 to 1 and a consolidated current ratio of 1.30 to 1. The
Company will not be allowed to incur additional debt over $8.0 million without
consent from Regions Bank. The actual funding of the Finance Facility is to
commence following effectiveness of the Shipyard contract and once the Company
has spent $30.0 million related to the conversion of
- 47 -
the Midnight Express. The Company had spent $19.5 million related to the
conversion as of December 31, 2002.
The term loan facility of the Finance Facility is a three-year debt structure
with a 10-year amortization payment schedule with semi-annual payments. The
pricing for this facility is 3.25% over LIBOR. Regions Bank and EDC would
require the Company to maintain the same collateral and covenants as included in
the construction financing depicted above.
Two conditions remain that the Shipyard must fulfill prior to the conversion
contract becoming effective. The Company has agreed to extend the date by which
these conditions must be met to April 2, 2003. If these conditions are not met,
the conversion contract will become null and void and the Company may have to
submit the project for re-bid. The delay resulting from re-bidding and
re-awarding the contract could result in substantial delay in delivery of the
vessel and thus would cause a delay in the implementation of the Company's
deepwater strategy and the start of operations of the Midnight Express.
Additionally, the cost of the contract may increase and the Company will incur
costs to move the vessel to another shipyard. It is anticipated that the
conversion will be performed by another Canadian shipyard; however, the
inability of the Company to complete the conversion in a Canadian shipyard would
result in the loss of the EDC portion of the financing of the conversion. If the
Company awards the project to a shipyard that is not located in Canada, the
Company will have to secure additional financing for this project.
In December 2002, the Company entered into a purchase agreement with Global
Marine for the Midnight Wrangler (see Note 6) at a cost of approximately $10.8
million. The Company took delivery of the vessel in March 2003. The purchase of
the vessel was financed by Global Marine over a five-year period with monthly
payments, including 7% per annum interest, of approximately $0.2 million plus a
$1.0 million payment at the purchase date in March 2003 and another $1.0 million
payment at the end of the five-year period. There is no debt recorded on the
Company's book as of December 31, 2002, as the purchase was contingent upon
delivery of the vessel in March 2003.
As of December 31, 2002, the fair value of the Company's debt obligations
approximated carrying value.
The Company's debt consists of the following (in thousands):
DECEMBER 31,
2002 2001
----------- -----------
Receivable line of credit ................... $ 4,271 $ --
Other debt (Note 9) ......................... 60 --
----------- -----------
Total debt ......................... 4,331 --
Less current portion ............... 4,285 --
----------- -----------
Total long-term debt ............... $ 46 $ --
=========== ===========
In March 2003, the Company finalized a $9.25 million, seven-year term loan with
GE Commercial Equipment Financing (GE). The loan is structured so that the
Company received $8.0 million immediately and GE retained $1.25 million as a
security deposit. The interest rate on the term loan is the 30-day commercial
paper rate plus 2.03% and includes prepayment penalties of 2% for the first
twelve months, 1% for the second twelve months and 0% thereafter. The term loan
is structured to have monthly payments over seven years. The collateral for the
loan is the Midnight Eagle. The Company intends to utilize the proceeds from the
loan to fund the improvements to the Midnight Wrangler and a portion of the
Midnight Express conversion costs.
8. INCOME TAXES:
In connection with the Public Offering, the Company became subject to corporate
level taxation and recorded a $2.6 million charge based upon cumulative book and
tax basis differences at the date of change in taxpayer status. The Company
recorded a $0.2 million provision (a 35% effective tax rate) attributable to
operating earnings for the year ended December 31, 2002 and a $0.8 million
provision (a 35% effective tax rate) attributable to operating earnings after
the Public Offering for the period ended December 31, 2001. From 1997 until the
Public Offering the Company had not been subject to income taxes.
- 48 -
The provision for income taxes reflected in the statement of operations
consisted of the following for the years ended December 31, 2002, 2001 and 2000
(in thousands):
YEARS ENDED DECEMBER 31,
2002 2001 2000
----------- ----------- -----------
Current tax benefit ............................................................ $ -- $ 808 $ --
Deferred tax expense ........................................................... (213) (4,241) --
----------- ----------- -----------
$ (213) $ (3,433) $ --
=========== =========== ===========
Reconciliations of the differences between income taxes from operations computed
at the federal statutory tax rate and income taxes recorded follow (in
thousands):
YEARS ENDED DECEMBER 31,
2002 2001 2000
----------- ----------- -----------
Income tax benefit (expense) computed at the federal statutory tax rate ........ $ (207) $ (1,149) $ 552
Increase attributable to:
Non-taxable income due to tax status ....................................... -- 292 (552)
Impact of cumulative differences in book and tax basis (Note 2) ............ -- (2,608) --
State taxes and other ...................................................... (6) 32 --
----------- ----------- -----------
Income tax expense ............................................................. $ (213) $ (3,433) $ --
=========== =========== ===========
The components of the Company's deferred taxes at December 31, 2002 and 2001
follow (in thousands):
YEAR ENDED YEAR ENDED
DECEMBER 31, 2002 DECEMBER 31, 2001
LONG- LONG-
CURRENT TERM CURRENT TERM
----------- ----------- ----------- -----------
Deferred tax assets:
Allowance for doubtful accounts ............................... $ 428 $ -- $ 76 $ --
Other accruals ................................................ 35 -- 88 --
Tax loss carryforward ......................................... -- 3,762 -- 1,416
----------- ----------- ----------- -----------
Total deferred tax assets ....................................... $ 785 $ 3,762 $ 164 $ 1,416
----------- ----------- ----------- -----------
Deferred tax liabilities:
Property, plant and equipment, and other ...................... $ -- $ (5,407) $ -- $ (2,561)
Drydocking .................................................... -- (991) -- (1,135)
Prepaid expenses .............................................. (1,072) -- (699) --
----------- ----------- ----------- -----------
Total deferred tax liabilities .................................. $ (1,072) $ (6,398) $ (699) $ (3,696)
----------- ----------- ----------- -----------
Net deferred tax liability ...................................... $ (287) $ (2,636) $ (535) $ (2,280)
=========== =========== =========== ===========
9. RELATED PARTY TRANSACTIONS:
The Company purchases catering services for the galleys of some of its vessels
from a company partially owned by Mrs. Stockstill. Purchases for 2002, 2001 and
2000 totaled $165,000, $33,000 and zero, respectively. The Company also
purchased fuel from a company partially owned by Mrs. Stockstill. Purchases for
2002, 2001 and 2000 totaled $234,000, $53,000 and $282,000, respectively.
In December 2002, the Company entered into a five-year lease agreement for a
rental property for client and provider entertainment purposes from an
investment holding company wholly-owned by Mr. Stockstill. The annual lease
payments approximate $51,000.
During 2002, the Company purchased a leisure fishing vessel for client and
provider entertainment purposes from an investment holding company wholly-owned
by Mr. Stockstill. The total cost of the vessel was approximately $0.1 million,
of which $41,000 was paid by the Company in cash during 2002 plus the Company
assumed debt of $60,000. The debt
- 49 -
will be paid by the Company in monthly installments over a five-year period and
is classified as other debt on the balance sheet (see Note 7).
10. SIGNIFICANT CUSTOMERS:
No individual customer made up more than 10% of the revenues for the years ended
December 31, 2002 or 2001. Approximately 27% of the Company's revenues were
derived from two customers during 2000.
11. SEVERANCE AND REORGANIZATIONAL COSTS:
During 1999, the Company consolidated its corporate and operations offices. As
part of this process, the Company incurred certain one-time employee severance,
office closure and relocation costs totaling approximately $0.2 million. In
addition, because of this consolidation process, the Company recognized a charge
of approximately $1.5 million during 1999 for the termination agreement
associated with one employee (see Note 12). The Company also recorded a $0.5
million charge in 2000 primarily associated with the termination of another
employee (see Note 12). These severance and reorganization costs have been
reflected in the caption "Other Operating Expense" in the Statements of
Operations.
12. COMMITMENTS AND CONTINGENCIES:
Employment Agreements - The Company had an employment agreement with an employee
and also granted in 1996 a ten-year option to this employee to purchase 395,000
shares of the Company's common stock with an exercise price of $0.51 per share.
In 1999, the Company entered into a termination agreement with this employee,
canceling the employment agreement and the options. The termination agreement
called for payments totaling $1.5 million. This amount was paid in full in 2001.
In 1998, the Company entered into an employment agreement with an employee and
also granted a ten-year option to this employee to purchase 77,900 shares of the
Company's common stock at an exercise price of $4.62 per share. An additional
"fair market value" grant of options to purchase 319,200 shares of the Company's
common stock was made to this employee in 1998, with an exercise price of $9.99
per share. The exercise prices of the respective options equaled or exceeded
management's estimate of the fair value of the Company's stock at the dates of
grant. In 2000, the Company entered into a termination agreement with this
employee, canceling the employment agreement and the options. The termination
agreement called for payments totaling approximately $0.4 million. The entire
balance was paid as of December 31, 2001.
The Company presently has employment agreements with two officers. One
employment agreement expires on July 30, 2004 and includes severance benefits
equal to twelve months salary for this individual as well as a non-compete
clause for a period of twelve months after termination. This employment
agreement automatically renews for successive one-year terms unless terminated.
The other employment agreement expires on December 31, 2003 and also includes
severance benefits equal to twelve months salary for this individual as well as
a non-compete clause for a period of twelve months after termination. This
employment agreement is only renewable upon written agreement from the officer
and the Company.
Lease Commitments - The Company's obligations under non-cancellable operating
lease commitments as of December 31, 2002 totaled $3.9 million for 2003, $3.9
million for 2004, $1.1 million for 2005, $0.1 million for 2006, $0.1 million for
2007 and no amounts million thereafter. The majority of the obligation relates
to the Company's charter of the Midnight Arrow.
The Company also leases real property in the normal course of business under
varying operating leases that generally provide for fixed monthly rentals. Rent
expense for the years ending December 31, 2002, 2001 and 2000 was $448,000,
$420,000 and $306,000, respectively.
In early 2000, the Company commenced a five-year new-build charter for the
Midnight Arrow, a DP-2 deepwater subsea construction vessel. The long-term
charter is with Adams Offshore Ltd. and expires in March 2005. The charter
amount includes the marine crew, maintenance and repairs, drydock costs and
certain insurance coverages. Under the terms of the charter, the Company has the
exclusive option to purchase the vessel for $8.25 million or the ability to
extend the charter for an additional two years at the end of the charter period.
This charter is being accounted for as an operating lease.
- 50 -
In May 2002, the Company entered into an agreement with Cable Shipping, Inc. to
time charter a vessel, the G. Murray, under a three-year contract at a rate of
$18,500 per day. The time charter commenced in the third quarter of 2002 and the
vessel was renamed the Midnight Hunter. However, in January 2003, the Company
terminated the time charter because of the vessel's failure to meet certain
specifications outlined in the charter agreement. The Company filed a lawsuit as
discussed below. The Company recognized a $0.9 million charge ($0.6 million net
of the income tax effect) during the fourth quarter of 2002.
The Company has executed contracts with several critical equipment suppliers
related to the conversion of the Midnight Express. These contracts aggregate
$39.0 million, of which $6.8 million had been paid as of December 31, 2002, and
are generally contingent upon the arrangement of permanent financing for the
Midnight Express. In the event the Company terminates these contracts, the
Company is required to pay certain of these suppliers' costs incurred to date
plus 10% while other suppliers are entitled to the full value of the contract,
depending upon the terms of the relevant agreement. The Company believes its
present termination cost exposure on these contracts totals approximately $10.5
million. In addition, the Company has executed contracts with several suppliers
for various equipment to be used in connection with the installation of a
modular lay system on the Midnight Wrangler, as well as the addition thereon of
accommodations and other equipment. These contracts aggregate $2.4 million, of
which $0.8 million had been paid as of December 31, 2002, and the present
termination cost exposure on these contracts totals approximately $1.3 million.
The Company also leases real property in the normal course of business under
varying operating leases that generally provide for fixed monthly rentals. Rent
expense for the years ending December 31, 2002, 2001 and 2000 was $448,000,
$420,000 and $306,000, respectively.
Contingencies - The Company has been named as a defendant in a stockholder class
action suit filed by purported stockholders regarding the Public Offering. This
lawsuit, Karl L. Kapps, et. al. v. Torch Offshore, Inc. et. al., No. 02-00582,
which seeks unspecified monetary damages, was filed on March 1, 2002 in U.S.
District Court for the Eastern District of Louisiana. The lawsuit was dismissed
on December 19, 2002 for failure to state a claim upon which relief could be
granted. The plaintiff has appealed to the U.S. Court of Appeals for the Fifth
Circuit. The Company believes the allegations in this lawsuit are without merit
and intends to continue to vigorously defend this lawsuit. Even so, an adverse
outcome in this class action litigation could have a material adverse effect on
the Company's financial condition or results of operations.
The Company has been named as a defendant in a lawsuit (Bluffview Capital, LP v.
Torch Offshore, Inc., No. 2002-7662, filed in the 134th Judicial District Court,
Dallas County, Texas on August 26, 2002) brought by a former service provider.
The plaintiff was originally hired to assist the Company in obtaining financing,
among other services. The Company terminated the relationship and is disputing
the plaintiff's interpretation of certain provisions regarding the services to
be provided and the calculation of fees allegedly earned. The Company's
management believes that it has complied with all of the provisions of the
contract and intends to continue to vigorously defend its position in this
matter. Nevertheless, an adverse outcome in the litigation could have an adverse
effect on the Company's financial condition or results of operations.
The Company terminated the charter of the Midnight Hunter on January 24, 2003,
as discussed above. The Company filed a lawsuit (Torch Offshore, L.L.C. v. The
M/V Midnight Hunter and Cable Shipping, Inc., et al., No. 03-0343, filed in the
United States District Court, Eastern District of Louisiana on February 4, 2003)
seeking an order, which was granted by the court, attaching and arresting the
Midnight Hunter as security for the Company's claims related to such
termination. A $1.5 million standby letter of credit issued to secure the
Company's payments under the charter remains outstanding. The claims will be
settled by arbitration in London, England. The Company's management believes the
amount of the claim is justified and we intend to vigorously pursue this matter.
Nevertheless, an adverse outcome from the litigation/arbitration could have an
adverse effect on our financial condition or results of operations.
- 51 -
In March 2003, the Company filed a lawsuit (Torch Offshore, Inc. v. Newfield
Exploration Company, No. 03-0735, filed in the United States District Court,
Eastern District of Louisiana on March 13, 2003) against Newfield Exploration
Company (Newfield) claiming damages of approximately $2.1 million related to
work completed for Newfield in the Gulf of Mexico at Grand Isle Block 103-A. The
lawsuit alleges that the Company did not receive all compensation to which it
was entitled pursuant to the contract. As of December 31, 2002, the Company has
recorded an amount attributable to this claim based upon the Company's
contractual rights under its agreement with Newfield. The Company intends to
vigorously pursue the matter, the ultimate resolution of which could materially
impact currently recorded amounts in the future.
Because of the nature of its business, the Company is subject to various other
claims. The Company has engaged legal counsel to assist in defending all legal
matters, and management intends to vigorously defend all claims. The Company
does not believe, based on all available information, that the outcome of these
matters will have a material effect on its financial condition or results of
operations.
13. STOCKHOLDERS' EQUITY:
Treasury Stock - In August 2001, the Company's Board of Directors approved the
repurchase of up to $5.0 million of the Company's outstanding common stock.
Purchases will be made on a discretionary basis in the open market or otherwise
over a period of time as determined by management subject to market conditions,
applicable legal requirements and other factors. As of December 31, 2002,
709,868 shares had been repurchased at a total cost of approximately $4.2
million.
Stock Option Plan - The Company's 2001 Long-Term Incentive Plan authorizes 3.0
million shares of the Company's common stock to be granted to employees,
directors and affiliates in the form of options, stock, phantom stock,
performance based stock or stock appreciation rights. As of December 31, 2002,
stock options covering 369,442 shares of common stock with a weighted average
price of $11.80 per share, and 65,675 shares of restricted stock, both vesting
generally over five years, were outstanding. Prior to the Public Offering grant,
only stock option grants associated with the Company's predecessor were
outstanding (see Note 12).
The following table shows the changes in options outstanding under the 2001
Long-Term Incentive Plan for the years ended December 31, 2002 and 2001:
WEIGHTED
NUMBER OF AVERAGE EXERCISE
OPTIONS PRICE
--------- ----------------
Granted ................................... 255,943 $ 16.00
Cancelled ................................. 32,188 16.00
Exercised ................................. -- --
---------
Outstanding at December 31, 2001 ............ 223,755 16.00
Granted ................................... 233,000 8.50
Cancelled ................................. 87,313 13.76
Exercised ................................. -- --
---------
Outstanding at December 31, 2002 ............ 369,442 $ 11.80
=========
The following table summarizes information on stock options outstanding and
exercisable as of December 31, 2002, pursuant to the 2001 Incentive Plan:
OPTIONS OUTSTANDING OPTIONS EXERCISABLE
---------------------------------------------------------- -----------------------------------
WEIGHTED
AVERAGE WEIGHTED WEIGHTED
RANGE OF SHARES REMAINING AVERAGE SHARES AVERAGE
EXERCISE PRICES OUTSTANDING CONTRACTUAL LIFE EXERCISE PRICE EXERCISABLE EXERCISE PRICE
--------------- ----------- ---------------- -------------- ----------- --------------
$5.23 - $5.61 18,000 9.7 years $5.28 -- --
$8.77 188,000 9.4 years $8.77 4,000 $8.77
$16.00 163,442 8.4 years $16.00 38,688 $16.00
- 52 -
14. EMPLOYEE BENEFIT PLAN:
The Company has a 401(k) defined contribution plan whereby eligible employees
are allowed to contribute on a tax deferred basis up to 15% of their
compensation (subject to certain limitations) for investment within the plan.
Earnings from the plan accumulate to the benefit of the employees on a
tax-deferred basis. The Company matches employee contributions up to 6% of the
respective employees' compensation. Plan participants vest in the Company's
matching contributions over a five-year period. The amount contributed to the
plan by the Company totaled $340,000 for 2002, $318,000 for 2001 and $341,000
for 2000.
15. QUARTERLY FINANCIAL DATA (UNAUDITED):
Following is a summary of consolidated interim financial results:
FISCAL YEAR 2002 QUARTERS
(in thousands, except per share data) FIRST SECOND THIRD FOURTH
---------- ---------- ---------- ----------
Revenues ........................................................ $ 16,725 $ 12,910 $ 13,833 $ 24,522
Operating Income (Loss) ......................................... 799 (679) (477) 733
Net Income (Loss) ............................................... 563 (414) (298) 544
Net Income (Loss) Attributable to Common Stockholders ........... 563 (414) (298) 544
Basic Earnings (Loss) Per Share ................................. 0.04 (0.03) (0.02) 0.04
Diluted Earnings (Loss) Per Share ............................... 0.04 (0.03) (0.02) 0.04
FISCAL YEAR 2001 QUARTERS
FIRST SECOND THIRD FOURTH
---------- ---------- ---------- ----------
Revenues ........................................................ $ 14,491 $ 14,317 $ 15,596 $ 14,648
Operating Income (Loss) ......................................... 1,680 1,546 1,334 (6)
Net Income (Loss) ............................................... 769 (2,384) 997 67
Net Income (Loss) Attributable to Common Stockholders ........... 655 (2,460) 997 67
Basic Earnings (Loss) Per Share ................................. 0.09 (0.26) 0.07 0.01
Diluted Earnings (Loss) Per Share ............................... 0.09 (0.26) 0.07 0.01
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
Arthur Andersen LLP, also referred to as Andersen, audited our financial
statements for 2001 and had served as our independent accountants since 1997. On
June 28, 2002, we dismissed Andersen, as our independent accountants effective
as of that date. The decision to dismiss Andersen was recommended by the Audit
Committee of the Board of Directors and was approved by the Board of Directors.
Andersen ceased to practice before the SEC effective August 31, 2002.
Andersen's report on Torch Offshore, Inc.'s financial statements for the fiscal
year ended December 31, 2001 did not contain an adverse opinion or disclaimer of
opinion and was not qualified or modified as to uncertainty, audit scope or
accounting principles. During the fiscal year ended December 31, 2001 and the
period from January 1, 2002 through the date of Andersen's termination, there
were no disagreements between us and Andersen on any matter of accounting
principles or practices, financial statement disclosure, or auditing scope or
procedure, which disagreements, if not resolved to the satisfaction of Andersen,
pursuant to Item 304(a)(l)(v) of Regulation S-K, would have caused it to make
reference to the subject matter of the disagreement in its report.
In June 2002, as required under the regulations of the SEC, we provided Andersen
with a copy of our disclosure in connection with this matter and requested
Andersen to furnish us with a letter addressed to the SEC stating whether it
agreed with our statements and, if not, stating the respects in which it did not
agree. Andersen's letter was filed as Exhibit 16.1 to our Current Report on Form
8-K filed with the SEC on July 3, 2002.
Effective June 28, 2002, we engaged Ernst & Young LLP as our new independent
accountants for the fiscal year ended December 31, 2002. The decision to appoint
Ernst & Young LLP was recommended by the Audit Committee of the Board of
Directors and was approved by the Board of Directors. During the two fiscal
years ended December 31, 2001 and December 31, 2000, and the subsequent interim
period through June 28, 2002, we did not consult with Ernst & Young LLP
regarding any of the matters or events set forth in Item 304(a)(2)(i) and (ii)
of Regulation S-K.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information required by this item is set forth under the captions "Election
of Directors" and "Compliance with Section 16(a) of the Exchange Act" in the
Company's definitive Proxy Statement (the "2003 Proxy Statement") for its annual
meeting of stockholders to be held on May 15, 2003, which sections are
incorporated herein by reference.
Pursuant to Item 401(b) of Regulation S-K, the information required by this item
with respect to executive officers of the Company is set forth in Part I of this
report.
ITEM 11. EXECUTIVE COMPENSATION
The information required by this item is set forth in the sections entitled
"Election of Directors - Director Compensation" and "Executive Compensation" in
the 2003 Proxy Statement, which sections are incorporated herein by reference.
- 53 -
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Except as set forth below, the information required by this item is set forth in
the section entitled "Security Ownership of Certain Beneficial Owners and
Management" in the 2003 Proxy Statement, which section is incorporated herein by
reference.
SECURITIES AUTHORIZED FOR ISSUANCE UNDER EQUITY COMPENSATION PLANS
The following table provides information as of December 31, 2002, with respect
to equity compensation plans under which our common stock is authorized for
issuance.
NUMBER OF SECURITIES
REMAINING AVAILABLE FOR
NUMBER OF SECURITIES TO WEIGHTED AVERAGE FUTURE ISSUANCE UNDER EQUITY
BE ISSUED UPON EXERCISE EXERCISE PRICE OF COMPENSATION PLANS
OF OUTSTANDING OPTIONS, OUTSTANDING OPTIONS, (EXCLUDING SECURITIES
PLAN CATEGORY WARRANTS AND RIGHTS WARRANTS AND RIGHTS REFLECTED IN FIRST COLUMN)
------------- ----------------------- ------------------- -----------------------------
Equity Compensation Plans Approved by
Stockholders ...................................... 369,442 $ 11.80 2,564,883
Equity Compensation Plans Not Approved
by Stockholders ................................... -- -- --
------- ---------
Total at December 31, 2002 .......................... 369,442 $ 11.80 2,564,883
See Note 13 to our financial statements for further information regarding the
significant features of the above plan.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information required by this item is set forth in the section entitled
"Election of Directors - Certain Transactions" in the 2003 Proxy Statement,
which section is incorporated herein by reference.
ITEM 14. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures. Our chief executive officer
and chief financial officer, with the participation of management, have
evaluated the effectiveness of our "disclosure controls and procedures" (as
defined in Rules 13a-14(c) and 15d-14(c) under the Securities Exchange Act of
1934) as of a date within 90 days prior to the filing of this quarterly report
on Form 10-Q. Based on their evaluation, they have concluded that our disclosure
controls and procedures are effective in alerting them in a timely manner to
material information relating to Torch Offshore, Inc. required to be disclosed
in our periodic Securities and Exchange Commission filings under the Securities
Exchange Act of 1934.
Changes in Internal Controls. There were no significant changes in our internal
controls or in other factors that could significantly affect these internal
controls subsequent to the date of their evaluation, including any corrective
actions taken with regard to significant deficiencies and material weaknesses.
- 54 -
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) 1. FINANCIAL STATEMENTS:
Reports of Independent Auditors ............................................................................. 35
Consolidated Balance Sheets as of December 31, 2002 and 2001 ................................................ 37
Consolidated Statements of Operations for the Years Ended December 31, 2002, 2001 and 2000 .................. 38
Consolidated Statements of Changes in Stockholders' Equity for the Years Ended December 31,
2002, 2001 and 2000 ....................................................................................... 39
Consolidated Statements of Cash Flows for the Years Ended December 31, 2002, 2001 and 2000 .................. 40
Notes to Consolidated Financial Statements .................................................................. 41
2. FINANCIAL STATEMENT SCHEDULES:
All other financial statement schedules are omitted because the
information is not required or because the information required is in the
financial statements or notes thereto.
4(a). EXHIBITS:
The following exhibits are filed herewith unless otherwise indicated:
*3.1 -- Certificate of Incorporation (Incorporated by reference to Exhibit 3.1 to the Company's
Registration Statement on Form S-1 (Registration No. 333-54120)).
*3.2 -- Bylaws (Incorporated by reference to Exhibit 3.2 to the Company's Registration Statement on Form
S-1 (Registration No. 333-54120)).
*3.3 -- Certificate of Amendment to Certificate of Incorporation (Incorporated by reference to Exhibit 3.3
to the Company's Registration Statement on Form S-1 (Registration No. 333-54120)).
*4.1 -- Form of specimen common stock certificate (Incorporated by reference to Exhibit 4.1 to the
Company's Registration Statement on Form S-1 (Registration No. 333-54120)).
*4.2 -- Registration Rights Agreement, dated June 6, 2001, among the Company, Friends of Lime Rock LP and
Riverside Investments LLC (Incorporated by reference to Exhibit 4.1 to the Company's Current
Report on Form 8-K filed June 12, 2001 (SEC File No. 000-32855)).
*10.1 -- Contribution Agreement dated January 15, 2001 among Torch, Inc., Friends of Lime Rock LP,
Riverside Investments LLC and Torch Offshore, Inc. (Incorporated by reference to Exhibit 10.1 to
the Company's Registration Statement on Form S-1 (Registration No. 333-54120)).
*10.2 -- Torch Offshore, Inc. 2001 Long-Term Incentive Plan (Incorporated by reference to Exhibit 10.2 to
the Company's Registration Statement on Form S-1 (Registration No. 333-54120)).
*10.8 -- Form of Indemnification Agreement (Incorporated by reference to Exhibit 10.9 to the Company's
Registration Statement on Form S-1 (Registration No. 333-54120)).
*10.10 -- Pipelay Services Contract between Union Oil Company of California and Torch, Inc., a Louisiana
corporation, dated January 4, 2001 (Incorporated by reference to Exhibit 10.12 to the Company's
Registration Statement on Form S-1 (Registration No. 333-54120)).
*10.14 -- "Supplytime 89" - dated 31 May 2002 with respect to "G. Murray" TBN "Midnight Hunter"
(Incorporated by reference to Exhibit 10.1 to the Company's Quarterly Report on Form 10-Q for the
period ended June 30, 2002).
*10.15 -- Amendment No. 1 Dated 25 June 2002 to "Supplytime 89" - dated 31 May 2002 with respect to "G.
Murray" TBN "Midnight Hunter" (Incorporated by reference to Exhibit 10.2 to the Company's
Quarterly Report on Form 10-Q for the period ended June 30, 2002).
*10.16 -- Loan Agreement By and Between Regions Bank and Torch Offshore, Inc. (Incorporated by reference to
Exhibit 10.1 to the Company's Quarterly Report on Form 10-Q for the period ended September 30,
2002).
- 55 -
*10.17 -- Memorandum of Agreement between Global Marine Systems Limited of East Saxon House and Torch
Offshore Inc. dated 27th November, 2002 (Incorporated by reference to Exhibit 99.2 to the
Company's Current Report on Form 8-K filed December 23, 2002).
*10.18 -- Credit Facility Agreement between (1) Torch Offshore Inc. (2) Global Marine Systems Limited
Relating to the Vessel "Wave Alert" to be Renamed "Midnight Wrangler" (Incorporated by reference
to Exhibit 99.3 to the Company's Current Report on Form 8-K filed December 23, 2002).
*10.19 -- Assignment of Insurances between (1) Torch Offshore Inc., as Assignor, and (2) Global Marine
Systems Limited, as Assignee (Incorporated by reference to Exhibit 99.4 to the Company's Current
Report on Form 8-K filed December 23, 2002).
*10.20 -- First Preferred Vanuatu Ship Mortgage on m.v. "Midnight Wrangler" formerly "Wave Alert" between
(1) Torch Offshore Inc., as Owner, and (2) Global Marine Systems Limited, as Mortgagee
(Incorporated by reference to Exhibit 99.5 to the Company's Current Report on Form 8-K filed
December 23, 2002).
10.21 -- Conversion Contract between Davie Maritime, Inc., as Builder, and Torch Express L.L.C., as Owner,
dated December 3, 2002
10.22 -- Loan Agreement by and among General Electric Capital Corporation ("Lender"), a Delaware
corporation, Torch Offshore, L.L.C. ("Borrower"), a Delaware limited liability company, and Torch
Offshore, Inc., a Delaware corporation ("Guarantor") and Promissory Note.
10.23 -- Continuing Guaranty by Torch Offshore, Inc., a Delaware Corporation, in favor of General Electric
Capital Corporation, a Delaware Corporation, Guarantying the Indebtedness of Torch Offshore,
L.L.C.
10.24 -- First Preferred Ship Mortgage Granted by Torch Offshore, L.L.C., Owner, in Favor of General
Electric Capital Corporation, Mortgagee, on the United States Flag Vessel Named Midnight Eagle.
10.25 -- Employment Agreement between Torch Offshore, Inc. and Robert E. Fulton dated July 30, 2002
10.26 -- Employment Agreement between Torch Offshore, Inc. and Willie J. Bergeron, Jr. dated December 31,
2002
21.1 -- List of subsidiaries of the Company.
23.1 -- Consent of Ernst & Young LLP.
99.1 -- Certification by Lyle G. Stockstill to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906
of the Sarbanes-Oxley Act of 2002.
99.2 -- Certification by Robert E. Fulton to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002.
---------------
* Incorporated by reference as indicated.
4(b). REPORTS ON FORM 8-K:
On December 23, 2002, we filed a report on Form 8-K, reporting
under Item 2, announcing that we had entered into an agreement
for the purchase of the Wave Alert, a 340-foot cable-laying
dynamically positioned vessel, from Global Marine Shipping
Limited and that we would rename the vessel the Midnight
Wrangler.
- 56 -
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 our
behalf by the undersigned, thereunto duly authorized on March 25, 2003.
TORCH OFFSHORE, INC.
Date: March 25, 2003 By: /s/ ROBERT E. FULTON
-----------------------------------
Robert E. Fulton
Chief Financial Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this report
has been signed below by the following persons on behalf of the registrant and
in the capacities and on the dates indicated.
SIGNATURE TITLE DATE
----------------------------------------------------- ---------------------------------------------- ---------------
/s/ LYLE G. STOCKSTILL Chairman of the Board and Chief March 25, 2003
----------------------------------------------------- Executive Officer
Lyle G. Stockstill (Principal Executive Officer)
/s/ LANA J. HINGLE STOCKSTILL Chief Administrative Officer, Secretary March 25, 2003
----------------------------------------------------- and Director
Lana J. Hingle Stockstill
/s/ ROBERT E. FULTON Chief Financial Officer March 25, 2003
----------------------------------------------------- (Principal Accounting and Financial Officer)
Robert E. Fulton
/s/ WILLIE BERGERON Chief Operating Officer March 25, 2003
-----------------------------------------------------
Willie Bergeron
/s/ CURTIS LEMONS Director March 25, 2003
-----------------------------------------------------
Curtis Lemons
/s/ ANDREW L. MICHEL Director March 25, 2003
-----------------------------------------------------
Andrew L. Michel
/s/ JOHN REYNOLDS Director March 25, 2003
-----------------------------------------------------
John Reynolds
/s/ KEN WALLACE Director March 25, 2003
-----------------------------------------------------
Ken Wallace
- 57 -
CERTIFICATIONS
CERTIFICATIONS REQUIRED BY RULE 13A-14 UNDER THE SECURITIES EXCHANGE
ACT OF 1934
I, Lyle G. Stockstill, certify that:
1. I have reviewed this annual report on Form 10-K of Torch
Offshore, Inc.;
2. Based on my knowledge, this annual report does not contain any
untrue statement of a material fact or omit to state a
material fact necessary to make the statements made, in light
of the circumstances under which such statements were made,
not misleading with respect to the period covered by this
annual report;
3. Based on my knowledge, the financial statements, and other
financial information included in this annual report, fairly
present in all material respects the financial condition,
results of operations and cash flows of the registrant as of,
and for, the periods presented in this annual report;
4. The registrant's other certifying officers and I are
responsible for establishing and maintaining disclosure
controls and procedures (as defined in Exchange Act Rules
13a-14 and 15d-14) for the registrant and we have:
(a) designed such disclosure controls and procedures to
ensure that material information relating to the
registrant, including its consolidated subsidiaries,
is made known to us by others within those entities,
particularly during the period in which this annual
report is being prepared;
(b) evaluated the effectiveness of the registrant's
disclosure controls and procedures based on the
evaluation as of a date within 90 days prior to the
filing date of this annual report (the "Evaluation
Date"); and
(c) presented in this annual report our conclusions about
the effectiveness of the disclosure controls and
procedures based on our evaluation as of the
Evaluation Date;
5. The registrant's other certifying officers and I have
disclosed, based on our most recent evaluation, to the
registrant's auditors and the audit committee of registrant's
board of directors (or persons performing the equivalent
functions):
(a) all significant deficiencies in the design or
operation of internal controls which could adversely
affect the registrant's ability to record, process,
summarize and report financial data and have
identified for the registrant's auditors any material
weaknesses in internal controls; and
(b) any fraud, whether or not material, that involves
management or other employees who have a significant
role in the registrant's internal controls; and
6. The registrant's other certifying officers and I have
indicated in this annual report whether or not there were
significant changes in internal controls or in other factors
that could significantly affect internal controls subsequent
to the date of our most recent evaluation, including any
corrective actions with regard to significant deficiencies and
material weaknesses.
Date: March 25, 2003 /s/ Lyle G. Stockstill
-------------------------------------------------
Lyle G. Stockstill
Chairman of the Board and Chief Executive Officer
- 58 -
I, Robert E. Fulton, certify that:
1. I have reviewed this annual report on Form 10-K of Torch
Offshore, Inc.;
2. Based on my knowledge, this annual report does not contain any
untrue statement of a material fact or omit to state a
material fact necessary to make the statements made, in light
of the circumstances under which such statements were made,
not misleading with respect to the period covered by this
annual report;
3. Based on my knowledge, the financial statements, and other
financial information included in this annual report, fairly
present in all material respects the financial condition,
results of operations and cash flows of the registrant as of,
and for, the periods presented in this annual report;
4. The registrant's other certifying officers and I are
responsible for establishing and maintaining disclosure
controls and procedures (as defined in Exchange Act Rules
13a-14 and 15d-14) for the registrant and we have:
(a) designed such disclosure controls and procedures to
ensure that material information relating to the
registrant, including its consolidated subsidiaries,
is made known to us by others within those entities,
particularly during the period in which this annual
report is being prepared;
(b) evaluated the effectiveness of the registrant's
disclosure controls and procedures based on the
evaluation as of a date within 90 days prior to the
filing date of this annual report (the "Evaluation
Date"); and
(c) presented in this annual report their conclusions
about the effectiveness of the disclosure controls
and procedures based on our evaluation as of the
Evaluation Date;
5. The registrant's other certifying officers and I have
disclosed, based on our most recent evaluation, to the
registrant's auditors and the audit committee of registrant's
board of directors (or persons performing the equivalent
functions):
(a) all significant deficiencies in the design or
operation of internal controls which could adversely
affect the registrant's ability to record, process,
summarize and report financial data and have
identified for the registrant's auditors any material
weaknesses in internal controls; and
(b) any fraud, whether or not material, that involves
management or other employees who have a significant
role in the registrant's internal controls; and
6. The registrant's other certifying officers and I have
indicated in this annual report whether or not there were
significant changes in internal controls or in other factors
that could significantly affect internal controls subsequent
to the date of our most recent evaluation, including any
corrective actions with regard to significant deficiencies and
material weaknesses.
Date: March 25, 2003 /s/ ROBERT E. FULTON
-----------------------
Robert E. Fulton
Chief Financial Officer
- 59 -
TORCH OFFSHORE, INC.
GLOSSARY OF CERTAIN INDUSTRY TERMS
BOE: Barrels of oil equivalent. A measure of aggregate production which
includes oil, condensate and natural gas.
Coiled tubing: A prefabricated single length of reeled pipe (2" to 4 1/2" in
diameter) used for delivering tools "down hole" for maintenance
purposes, as a flowline, and occasionally for drilling small diameter
wells.
Conventional pipelay: Process of offshore pipe installation whereby 40-foot segments, or
multiples thereof, of up to 60" diameter pipe are welded together,
coated, and tested on the deck of the pipelay barge. Each segment is
then connected to the prior segment and is submerged in the water as
the barge is moved by its anchor winches or thrusters.
Conventional mooring: One of three methods of positioning a floating drilling, installation
or production unit over a position on the sea floor. A vessel is
conventionally moored when from one to 12 anchor lines extend from
the vessel to the sea floor where they are attached to embedded
anchors of various types.
While adequate for positioning permanent or transient vessels in
shallow to intermediate depths, conventional moorings are impractical
in deeper waters as the combined weight of the anchors and lines can
exceed the variable deck load of the vessel being moored.
Deepwater: Generally considered to be water depths between 1,000 and 5,000 feet
(also see "ultra-deepwater").
DP: Dynamic positioning. A positioning system effected by thrusters on
the bow and stern of a vessel that holds the vessel in place without
a mooring system. Computers, which use satellite, acoustic and taut
wire reference systems, and which take into account wind and current
effects on the vessel, direct the thrusters. A fully redundant DP-2
system is capable of using more than one reference system in case its
primary system is not operational and can maintain position even with
the loss of an engine, computer or a thruster (either at the bow or
at the stern).
Drydock: A submersible floating barge, equipped with wing walls, which can be
submerged in order to allow a normal vessel to float into position
between the wing walls. The submerged barge is then de- ballasted in
order to lift the normal vessel completely out of the water. Major
maintenance and required inspections can then be performed. Upon
successful completion of these activities, the submersible barge is
again submerged. The normal vessel is re- floated and then removed
from between the wing walls.
Periodic "drydockings" are required on a three to five year cycle in
order for vessels to be maintained in class and hence to be eligible
for insurance and for commercial use on offshore projects. The cost
of any given drydocking is initially capitalized and then amortized
over the period until the next scheduled drydocking.
G-1
Flowline: Small diameter (3" to 12") pipelines that carry fluids. Flowlines are
used to collect produced fluids from wells and transport them to
treating and storage facilities, as well as to deliver other fluids
for injection into the wellbore.
J-lay: Describes one of two basic profiles used when installing subsea
pipelines, the other being S-lay. The "J" in the term describes the
curve in the pipe maintained by the dynamic positioning system and
the tensioners onboard the lay vessel.
The J-lay technique is only used on vessels equipped with dynamic
positioning and is favored for use in deepwater. The J-lay
methodology has intrinsic cost disadvantages that result from the use
of a single welding station as opposed to S-lay methodology where
multiple welding stations can be used, accelerating the lay rate of
the vessel and thereby reducing the installed cost of the pipeline.
However, the advantages inherent in reducing the number of times the
pipe is bent, as well as in the need for less tensioning capacity as
water depths increase, make this the favored method in deepwater.
Kips: 1,000 pounds. Unit used for measuring the tension which can be
applied to a pipeline. Tension capability is one determinant of the
depth capability of a pipelay vessel.
MARAD: U.S. Department of Transportation Maritime Administration.
Moonpool: A protected opening in the center of a vessel through which a
saturation diving system, remotely operated vehicle or other
specialized equipment may be deployed, allowing deployment in adverse
weather conditions.
Mooring: A means of anchoring a vessel to the seabed.
Reeled pipe: A prefabricated flowline or pipeline reeled onboard a lay
vessel for transportation, followed by offshore installation. Pipe up
to 18" in diameter can be installed using reels operating in either
the S-lay or J-lay mode.
Reel lay: Process of offshore pipe installation whereby pipe segments are
welded, tested and coated onshore and then wound onto a pipe reel in
one continuous length. Once the reel vessel is in position, the pipe
is unspooled onto the ocean floor as the vessel moves forward.
Riser: Typically a rigid or flexible section of pipe that connects a subsea
pipeline or well head to either a fixed or floating surface
processing facility.
Remotely operated Robotic vehicle that is manipulated from a mother ship, via an
vehicle: umbilical, in order to perform tasks and increase the efficiency of
subsea operations at depths where the use of divers is either unsafe,
uneconomical or technically impossible.
G-2
S-lay: Describes one of two basic profiles used when installing subsea
pipelines, the other being J-lay. The "S" in the term describes the
curve in the pipe maintained by the positioning system and the
tensioners onboard the lay vessel.
The S-lay technique can be used on either a conventionally moored
vessel or on one equipped with dynamic positioning. While more than
adequate in shallow and intermediate depths, S-lay installation is
impractical in ultra-deepwater because of ever increasing mooring and
tensioning loads.
Saturation diving: A type of diving normally required at water depths greater
than 200 feet. Divers are kept under pressure for an extended period
of time, often many days, in a specially designed habitat and lowered
to the seabed by way of a "diving bell" to perform subsea
construction tasks. At the end of a work shift, they return to the
surface but remain under pressure until they descend for their next
work shift. At the end of the project, they are slowly decompressed
over several days until they return to surface conditions.
Shelf: Continental shelf of the Gulf of Mexico with waters from 50 feet to
1,500 feet in depth.
Spar: A type of floating production hull, resembling a large annular
cylinder, with air chambers at the top, to provide buoyancy, and
ballast at the bottom, to provide stability.
Sponson: A structure projecting from the side of a vessel, designed to
increase lateral stability.
Spud: A metal fabricated pole driven into the mud to hold a barge
stationary. At least two spuds are needed to hold a barge in
position. Spuds are useful in water depths up to 25 feet.
Stinger: A structural member extending from the stern of a laybarge which is
designed to support the pipeline as it enters the water. The member
may be either rigid or articulated. Its purpose is to maintain the
minimum bending radius of the pipe.
Surface supply diving: Also called "mixed gas diving" or "bounce diving," it is a diving
technique performed in water depths of less than 200 feet. Divers
are linked to the surface by an umbilical containing compressed gas,
communication and safety lines. Such diving may be done for only
a limited duration and requires subsequent decompression to avoid
serious injury to the diver.
Tension leg platform: A form of floating production system characterized by the use of
rigid tendons that extend vertically from the sea floor to the hull. These
tendons are in "tension" as a result of the hull's buoyancy.
Tie-in: The process of connecting a pipeline to another pipeline, or a
pipeline to a riser, by means of flanges, mechanical connectors or
hyperbaric welding.
G-3
Trunkline: Also called a "transmission line" or an "export line," it is a
pipeline of 14" to 42" in diameter and lengths of up to hundreds of
miles that transports hydrocarbons from multiple production
facilities to an onshore pipeline network or to a process facility.
Ultra-Deepwater: Water depths in excess of 5,000 feet.
Umbilical: Control lines arranged in a bundle that sometimes also include power
cables and injection lines.
G-4
EXHIBIT INDEX
EXHIBIT
NUMBER DESCRIPTION
------ -------------------------------------------------------------------------------------------------
*3.1 -- Certificate of Incorporation (Incorporated by reference to Exhibit 3.1 to the Company's
Registration Statement on Form S-1 (Registration No. 333-54120)).
*3.2 -- Bylaws (Incorporated by reference to Exhibit 3.2 to the Company's Registration Statement on Form
S-1 (Registration No. 333-54120)).
*3.3 -- Certificate of Amendment to Certificate of Incorporation (Incorporated by reference to Exhibit 3.3
to the Company's Registration Statement on Form S-1 (Registration No. 333-54120)).
*4.1 -- Form of specimen common stock certificate (Incorporated by reference to Exhibit 4.1 to the
Company's Registration Statement on Form S-1 (Registration No. 333-54120)).
*4.2 -- Registration Rights Agreement, dated June 6, 2001, among the Company, Friends of Lime Rock LP and
Riverside Investments LLC (Incorporated by reference to Exhibit 4.1 to the Company's Current
Report on Form 8-K filed June 12, 2001 (SEC File No. 000-32855)).
*10.1 -- Contribution Agreement dated January 15, 2001 among Torch, Inc., Friends of Lime Rock LP,
Riverside Investments LLC and Torch Offshore, Inc. (Incorporated by reference to Exhibit 10.1 to
the Company's Registration Statement on Form S-1 (Registration No. 333-54120)).
*10.2 -- Torch Offshore, Inc. 2001 Long-Term Incentive Plan (Incorporated by reference to Exhibit 10.2 to
the Company's Registration Statement on Form S-1 (Registration No. 333-54120)).
*10.8 -- Form of Indemnification Agreement (Incorporated by reference to Exhibit 10.9 to the Company's
Registration Statement on Form S-1 (Registration No. 333-54120)).
*10.10 -- Pipelay Services Contract between Union Oil Company of California and Torch, Inc., a Louisiana
corporation, dated January 4, 2001 (Incorporated by reference to Exhibit 10.12 to the Company's
Registration Statement on Form S-1 (Registration No. 333-54120)).
*10.14 -- "Supplytime 89" - dated 31 May 2002 with respect to "G. Murray" TBN "Midnight Hunter"
(Incorporated by reference to Exhibit 10.1 to the Company's Quarterly Report on Form 10-Q for the
period ended June 30, 2002).
*10.15 -- Amendment No. 1 Dated 25 June 2002 to "Supplytime 89" - dated 31 May 2002 with respect to "G.
Murray" TBN "Midnight Hunter" (Incorporated by reference to Exhibit 10.2 to the Company's
Quarterly Report on Form 10-Q for the period ended June 30, 2002).
*10.16 -- Loan Agreement By and Between Regions Bank and Torch Offshore, Inc. (Incorporated by reference to
Exhibit 10.1 to the Company's Quarterly Report on Form 10-Q for the period ended September 30,
2002).
*10.17 -- Memorandum of Agreement between Global Marine Systems Limited of East Saxon House and Torch
Offshore Inc. dated 27th November, 2002 (Incorporated by reference to Exhibit 99.2 to the
Company's Current Report on Form 8-K filed December 23, 2002).
*10.18 -- Credit Facility Agreement between (1) Torch Offshore Inc. (2) Global Marine Systems Limited
Relating to the Vessel "Wave Alert" to be Renamed "Midnight Wrangler" (Incorporated by reference
to Exhibit 99.3 to the Company's Current Report on Form 8-K filed December 23, 2002).
*10.19 -- Assignment of Insurances between (1) Torch Offshore Inc., as Assignor, and (2) Global Marine
Systems Limited, as Assignee (Incorporated by reference to Exhibit 99.4 to the Company's Current
Report on Form 8-K filed December 23, 2002).
*10.20 -- First Preferred Vanuatu Ship Mortgage on m.v. "Midnight Wrangler" formerly "Wave Alert" between
(1) Torch Offshore Inc., as Owner, and (2) Global Marine Systems Limited, as Mortgagee
(Incorporated by reference to Exhibit 99.5 to the Company's Current Report on Form 8-K filed
December 23, 2002).
10.21 -- Conversion Contract between Davie Maritime, Inc., as Builder, and Torch Express L.L.C., as Owner,
dated December 3, 2002
10.22 -- Loan Agreement by and among General Electric Capital Corporation ("Lender"), a Delaware
corporation, Torch Offshore, L.L.C. ("Borrower"), a Delaware limited liability company, and Torch
Offshore, Inc., a Delaware corporation ("Guarantor") and Promissory Note.
10.23 -- Continuing Guaranty by Torch Offshore, Inc., a Delaware Corporation, in favor of General Electric
Capital Corporation, a Delaware Corporation, Guarantying the Indebtedness of Torch Offshore,
L.L.C.
10.24 -- First Preferred Ship Mortgage Granted by Torch Offshore, L.L.C., Owner, in Favor of General
Electric Capital Corporation, Mortgagee, on the United States Flag Vessel Named Midnight Eagle.
10.25 -- Employment Agreement between Torch Offshore, Inc. and Robert E. Fulton dated July 30, 2002
10.26 -- Employment Agreement between Torch Offshore, Inc. and Willie J. Bergeron, Jr. dated December 31,
2002
21.1 -- List of subsidiaries of the Company.
23.1 -- Consent of Ernst & Young LLP.
99.1 -- Certification by Lyle G. Stockstill to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906
of the Sarbanes-Oxley Act of 2002.
99.2 -- Certification by Robert E. Fulton to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002.
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* Incorporated by reference as indicated.