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, 2001
| | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
FOR THE TRANSITION PERIOD FROM _____________ TO
COMMISSION FILE NUMBER 1-7573
PARKER DRILLING COMPANY
(Exact name of registrant as specified in its charter)
Delaware 73-0618660
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(State or other jurisdiction of (I.R.S. Employer Identification No.)
incorporation or organization)
1401 Enclave Parkway, Suite 600, Houston, Texas 77077
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(Address of principal executive offices) (zip code)
Registrant's telephone number, including area code (281) 406-2000
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Securities registered pursuant to Section 12(b) of the Act: Name of each
exchange on which registered:
Common Stock, par value $.16 2/3 per share New York Stock Exchange, Inc.
- ------------------------------------------ -----------------------------
(Title of class)
Securities registered pursuant to Section 12(g) of the Act:
N/A
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(Title of class)
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. | |
As of January 31, 2002, 92,152,089 common shares were outstanding, and the
aggregate market value of the common shares (based upon the closing price of
these shares on the New York Stock Exchange) held by nonaffiliates was $497.7
million.
PARKER DRILLING COMPANY
TABLE OF CONTENTS
PART I Page No.
Item 1. Business 2
Item 2. Properties 9
Item 3. Legal Proceedings 14
Item 4. Submission of Matters to a Vote of Security Holders 15
Item 4a. Executive Officers 15
PART II
Item 5. Market for Registrant's Common Stock and
Related Stockholder Matters 17
Item 6. Selected Financial Data 18
Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations 19
Item 7a. Quantitative and Qualitative Disclosures about Market Risk 29
Item 8. Financial Statements and Supplementary Data 30
Item 9. Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure 65
PART III
Item 10. Directors and Executive Officers of the Registrant 65
Item 11. Executive Compensation 65
Item 12. Security Ownership of Certain Beneficial Owners
and Management 66
Item 13. Certain Relationships and Related Transactions 66
PART IV
Item 14. Exhibits, Financial Statement Schedule and
Reports on Form 8-K 67
Signatures 73
DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS
This Form 10-K contains 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. These
statements may be made directly in this document, or may be "incorporated by
reference," which means the statements are contained in other documents filed by
the Company with the Securities and Exchange Commission. All statements included
in this document, other than statements of historical facts, that address
activities, events or developments that the Company expects, projects, believes
or anticipates will or may occur in the future are "forward-looking statements,"
including without limitation:
*future operating results,
*future rig utilization and rental tool activity,
*future capital expenditures and investments in the acquisition and
refurbishment of rigs and equipment,
*repayment of debt,
*maintenance of the Company's revolver borrowing base, and
*expansion and growth of operations.
Forward-looking statements are based on certain assumptions and analyses
made by management of the Company in light of its experience and perception of
historical trends, current conditions, expected future developments and other
factors it believes are relevant. Although management of the Company believes
that its assumptions are reasonable based on current information available, they
are subject to certain risks and uncertainties, many of which are outside the
control of the Company. These risks and uncertainties include:
*worldwide economic and business conditions that adversely affect market
conditions and/or the cost of doing business,
*the pace of recovery in the U.S. economy and the demand for natural gas,
*fluctuations in the market prices of oil and gas,
*imposition of unanticipated trade restrictions,
*political instability,
*governmental regulations that adversely affect the cost of
doing business,
*adverse environmental events,
*adverse weather conditions,
*changes in concentration of customer and supplier relationships,
*unexpected cost increases for upgrade and refurbishment projects,
*changes in competition, and
*other similar factors (some of which are discussed in this
Form 10-K and in documents referred to in this Form 10-K).
Because the forward-looking statements are subject to risks and
uncertainties, the actual results of operations and actions taken by the Company
may differ materially from those expressed or implied by such forward-looking
statements. These risks and uncertainties are referenced in connection with
forward-looking statements that are included from time to time in this document.
Each forward-looking statement speaks only as of the date of this Form 10-K, and
the Company undertakes no obligation to publicly update or revise any
forward-looking statement.
1
PART I
Item 1. BUSINESS
GENERAL DEVELOPMENT
Parker Drilling Company was incorporated in the state of Oklahoma in 1954
after having been established in 1934 by its founder, Gifford C. Parker. The
founder was the father of Robert L. Parker, chairman and a principal
stockholder, and the grandfather of Robert L. Parker Jr., president and chief
executive officer. In March 1976, the state of incorporation of the Company was
changed to Delaware through the merger of the Oklahoma Corporation into its
wholly-owned subsidiary Parker Drilling Company, a Delaware corporation. Unless
otherwise indicated, the term "Company" refers to Parker Drilling Company
together with its subsidiaries and "Parker Drilling" refers solely to the
parent, Parker Drilling Company.
The Company is a leading worldwide provider of contract drilling and
drilling related services. Our primary operating areas include the transition
zones of the Gulf of Mexico, Nigeria and the Caspian Sea; the offshore waters of
the Gulf of Mexico and on land in international oil and gas producing regions.
The Company's current marketed rig fleet consists of 27 barge drilling and
workover rigs, seven offshore jackup rigs, four offshore platform rigs and 41
land rigs. The Company's barge drilling and workover rig fleet is dedicated to
transition zone waters, which are generally defined as coastal waters having
depths from five to 25 feet. The Company's offshore jackup and platform rig
fleets currently operate in the Gulf of Mexico market and are capable of
drilling in water depths up to 85 to 215 feet. The Company's land rig fleet
generally consists of premium and specialized deep drilling rigs, with 37 of its
41 marketed land rigs capable of drilling to depths of 15,000 feet or greater.
The diversity of the Company's rig fleet, both in terms of geographic location
and asset class, enables the Company to provide a broad range of services to oil
and gas operators around the world.
TRANSITION ZONE OPERATIONS
The Company provides contract drilling services in the transition zones,
which are coastal waters including lakes, bays, rivers and marshes, of the Gulf
of Mexico, the Caspian Sea and Nigeria, where barge rigs are the primary source
of drilling and workover services. Barge rigs are barges with drilling equipment
on board. They are towed to a drilling location at which time the hull is
submerged to the bottom to provide stability before operations begin. Given
their design, barge rigs work in shallow waters up to 25 feet.
U.S. Barge Drilling and Workover
The Company's U.S. market for its barge drilling rigs is the transition
zones of the Gulf of Mexico, primarily in Louisiana and, to a lesser extent,
Alabama and Texas, where conventional jackup rigs are unable to operate. This
area historically has been the world's largest market for shallow water barge
drilling. The Company, with 22 drilling and workover barges, is one of two
companies with a significant presence in this market.
Utilization and dayrates for drilling and workover barges in the U.S.
market remained at peak levels for the first three quarters of 2001, driven by
intense drilling activity for natural gas due to high natural gas prices which
were the result of a shortage of natural gas supplies during the 2000/2001
winter. By mid-2001, however, natural gas supplies proved to be more plentiful
than was thought to be the case, due in part to the decline in economic activity
in the U.S. Consequently, natural gas prices began to decline, and
2
utilization and dayrates followed. While there have been signs of increasing
activity in the Gulf of Mexico in early 2002, management believes that any
significant increase will only accompany a sustained improvement in the U.S.
economy driving increased demand for natural gas (for 2001 utilization rates of
Parker's fleet, please see the Properties section of this report).
International Barge Drilling
The Company's international barge drilling operations are focused in the
transition zones of Nigeria and the Caspian Sea. International markets typically
are more attractive than U.S. markets due to long-term contracts and higher
dayrates.
The Company is the leading provider of barge rigs in Nigeria, with four of
the eight rigs in this market. The Company has operated in Nigeria since 1996.
The Company owns and operates the world's largest Arctic barge rig in the
Caspian Sea. This rig currently is drilling its fourth well under an initial
three-year contract with seven one-year options.
OFFSHORE OPERATIONS
Jackup Drilling
The Company has seven shallow water jackup rigs in the Gulf of Mexico.
Like the U.S. barge rig market, utilization and dayrates remained at high levels
for most of 2001 before following natural gas prices down in the fourth quarter.
Platform Drilling
The Company's fleet of platform rigs consists of four modular
self-erecting rigs. These platform rigs consist of drilling equipment and
machinery arranged in modular packages that are transported to and self-erected
on fixed offshore platforms owned by oil companies. The Company believes that
the modular self-erecting design of the platform rigs provides a competitive
advantage due to lower mobilization and erection costs and smaller "footprint."
LAND OPERATIONS
General
The Company's land drilling operations specialize in the drilling of
difficult wells, often in remote locations and/or harsh environments. Since
beginning operations in 1934, the Company has operated in 53 foreign countries
and throughout the United States, making it one of the most geographically
diverse land drilling contractors in the world. All of the company's land rigs
operate in international locations.
The Company's international land drilling operations have focused
primarily in Latin America, the Asia Pacific region and the republics of the
former Soviet Union. The Company's operational expertise has enhanced its
reputation as a pioneer in being the first western company to enter new
"frontiers" of oil and gas development around the world. The Company was the
first to enter China in 1980 and has provided continuous drilling services to
this market. The Company was also the first western drilling contractor to enter
Russia in 1991 followed by Kazakhstan in 1993, which now is one of the Company's
most active markets.
3
While U.S. offshore utilization and dayrates declined in the fourth
quarter of 2001, international land activity began to increase, generating the
sector's highest quarterly revenue in more than three years. Given announced
spending plans by oil and gas companies, the increased solicitation of bids for
rigs and additional strategically-positioned rigs ready to go to work, the
Company believes that its international markets will continue to improve
throughout 2002.
International markets differ from the U.S. market in terms of competition,
nature of customers, equipment and experience requirements. The majority of
international drilling markets have the following characteristics: (i) a small
number of competitors; (ii) customers who typically are major, large independent
or foreign national oil companies; (iii) drilling programs in remote locations
and/or harsh environments requiring drilling equipment with a large inventory of
spare parts and other ancillary equipment; and (iv) difficult i.e high pressure,
deep, or geologically-challenging, wells requiring considerable experience to
drill.
Latin America. The Company has 18 land rigs located in the Latin American
drilling markets of Colombia, Peru, Ecuador and Bolivia. Colombia was the most
active market for the Company in Latin America in 2001, and the Company
announced a one-year contract extension for its four rigs drilling for BP in
that country. The Company also announced a contract to work for Pluspetrol in
the Camisea gas field in Peru.
Asia Pacific/Middle East/Africa. The Company has 14 land rigs located in
the Asia Pacific, Middle East and Africa drilling markets. Included are nine
helicopter transportable rigs located in this region due to the remoteness of
the mountainside and jungle drilling required to meet customer demand. This
market had increasing activity throughout the year, with new contracts in
Indonesia, New Zealand and Papua New Guinea.
Former Soviet Union. Nine of the Company's rigs are currently located in
the oil and gas producing regions of the former Soviet Union. The Company was
the first Western drilling contractor to enter this market, in 1991, and it
continued to be a major area of operations in 2001. The Company commenced
drilling on three new contracts in Kazakhstan during the year. Two of these rigs
are working in the Karachaganak field, and one in the Tengiz field. In addition,
the company signed two contracts in 2001 related to new work on Sakhalin Island
in Russia. The first contract is to build a rig for the Sakhalin 1 consortium,
which will own the rig upon completion of construction, and mobilize it to
location. Mobilization is expected to take place in mid-2002. The second
contract is to operate the rig for the consortium.
U.S. Operations
The Company announced an alliance with Heartland Rig International, (HRI)
whereby HRI acquired the exclusive rights to manufacture and market the
intellectual property of Parker Technology, L.L.C. HRI is leasing the Company's
rig-building facilities in New Iberia, Louisiana, in the transaction with a
right to purchase.
Specialty Services
Arctic Drilling. The Company has been one of the pioneers in arctic
drilling services and has developed technology to meet the demand for increased
drilling in these ecologically sensitive areas. Although originally developed
for the North Slope of Alaska, these technological developments and the
Company's general expertise in arctic drilling are assets to the Company in
marketing its services to operators in international markets with similar
environmental considerations, such as the Caspian Sea and Sakhalin Island.
4
Project Management. The Company has been active in managing drilling rigs
owned by third parties, generally oil companies that prefer to own the rig
equipment but do not have the technical expertise or labor resources to operate
the rig. During the year 2001, the Company operated 11 project management
contracts in five countries.
RENTAL TOOLS
Quail Tools, based in New Iberia, Louisiana, is a provider of premium
rental tools used for land and offshore oil and gas drilling and workover
activities. Approximately 65 percent of Quail's equipment is utilized in
offshore and coastal water operations. Since its inception in 1978, Quail's
principal customers have been major and independent oil and gas exploration and
production companies.
COMPETITION
The contract drilling industry is a competitive and cyclical business
characterized by high capital requirements and, in recent times, difficulty in
finding and retaining qualified field personnel.
In the Gulf of Mexico barge drilling and workover markets the Company
competes with one major competitor, Transocean Sedco Forex. In the jackup
market, there are numerous U.S. offshore contractors. In international land
markets, the Company competes with a number of international drilling
contractors but also with smaller local contractors in certain markets. However,
due to the high capital costs of operating in international land markets as
compared to the U.S. land market, the high cost of mobilizing land rigs from one
country to another, and the technical expertise required, there are usually
fewer competitors in international land markets. In international land and
offshore markets, experience in operating in challenging environments and
customer alliances have been factors in the selection of the Company in certain
cases, as well as the Company's patented drilling equipment for remote drilling
projects. The Company believes that the market for drilling contracts, both land
and offshore, will continue to be highly competitive for the foreseeable future.
Certain competitors have greater financial resources than the Company, which may
enable them to better withstand industry downturns, compete more effectively on
the basis of price, build new rigs or acquire existing rigs.
Management believes that Quail Tools is one of the leading rental tool
companies in the offshore Gulf of Mexico market. A number of Quail's competitors
in the Gulf of Mexico and the Gulf Coast land markets, however, are
substantially larger and have greater financial resources than Quail Tools.
CUSTOMERS
The Company believes it has developed a reputation for providing
efficient, safe, environmentally conscious and innovative drilling services. An
increasing trend indicates that a number of the Company's customers have been
seeking to establish exploration or development drilling programs based on
partnering relationships or alliances with a limited number of preferred
drilling contractors. Such relationships or alliances can result in longer-term
work and higher efficiencies that increase profitability for drilling
contractors at a lower overall well cost for oil and gas operators. The Company
is currently a preferred contractor for operators in certain United States and
international locations, which management believes is a result of the Company's
quality of equipment, personnel, service and experience.
The Company's drilling customer base consists of major, independent and
foreign-owned oil and gas companies. For fiscal year 2001, ChevronTexaco was the
Company's largest customer with approximately 15 percent of total revenues.
Shell Petroleum Development Company of Nigeria, the Company's largest customer
for 2000 and 1999, accounted for approximately 10 percent of total revenues in
both years.
5
CONTRACTS
The Company generally obtains drilling contracts through competitive
bidding. Under most contracts the Company is paid a daily fee, or dayrate. The
dayrate received is based on several factors, including: type of equipment,
services and personnel furnished; investment required to perform the contract;
location of the well; term of the contract; and competitive market forces.
The Company generally receives a lump sum fee to move its equipment to the
drilling site, which in most cases approximates the cost incurred by the
Company. U.S. contracts are generally for one to three wells with options, while
international contracts are more likely to be for multi-well long-term programs.
The Company provides project management services including logistics,
procurement, well design, engineering, site preparation and road construction in
an effort to help customers eliminate or reduce management overhead, which would
otherwise be necessary to supervise such services.
EMPLOYEES
At December 31, 2001, the Company employed 3,654 people, an increase of 3
percent from the 3,542 employed at December 31, 2000. The following table sets
forth the composition of the Company's employees.
December 31,
-------------------
2001 2000
---- ----
International drilling operations 2,444 2,109
U.S. drilling operations 878 1,175
Rental tool operations 140 107
Corporate and other 192 151
RISKS AND ENVIRONMENTAL CONSIDERATIONS
The operations of the Company are subject to numerous federal, state and
local laws and regulations governing the discharge of materials into the
environment or otherwise relating to environmental protection. Numerous
governmental agencies, such as the U.S. Environmental Protection Agency ("EPA"),
issue regulations to implement and enforce such laws, which often require
difficult and costly compliance measures that carry substantial administrative,
civil and criminal penalties or may result in injunctive relief for failure to
comply. These laws and regulations may require the acquisition of a permit
before drilling commences, restrict the types, quantities and concentrations of
various substances that can be released into the environment in connection with
drilling and production activities, limit or prohibit construction or drilling
activities on certain lands lying within wilderness, wetlands, ecologically
sensitive and other protected areas, require remedial action to prevent
pollution from former operations, and impose substantial liabilities for
pollution resulting from the Company's operations. Changes in environmental laws
and regulations occur frequently, and any changes that result in more stringent
and costly compliance could adversely affect the Company's operations and
financial position, as well as those of similarly situated entities operating in
the Gulf Coast market. While management believes that the Company is in
substantial compliance with current applicable environmental laws and
regulations, there is no assurance that compliance can be maintained in the
future.
The drilling of oil and gas wells is subject to various federal, state,
local and foreign laws, rules and regulations. The Company, as an owner or
operator of both onshore and offshore facilities including mobile
6
offshore drilling rigs in or near waters of the United States, may be liable for
the costs of removal and damages arising out of a pollution incident to the
extent set forth in the Federal Water Pollution Control Act, as amended by the
Oil Pollution Act of 1990 ("OPA"), the Outer Continental Shelf Lands Act
("OCSLA"), the Comprehensive Environmental Response, Compensation and Liability
Act ("CERCLA"), and the Resource Conservation and Recovery Act ("RCRA"), each as
amended from time to time. In addition, the Company may also be subject to
applicable state law and other civil claims arising out of any such incident.
The OPA and regulations promulgated pursuant thereto impose a variety of
regulations on "responsible parties" related to the prevention of oil spills and
liability for damages resulting from such spills. A "responsible party" includes
the owner or operator of a vessel, pipeline or onshore facility, or the lessee
or permittee of the area in which an offshore facility is located. The OPA
assigns liability of oil removal costs and a variety of public and private
damages to each responsible party.
The liability for a mobile offshore drilling rig is determined by whether
the unit is functioning as a vessel or is in place and functioning as an
offshore facility. If operating as a vessel, liability limits of $600 per gross
ton or $500,000, whichever is greater, apply. If functioning as an offshore
facility, the mobile offshore drilling rig is considered a "tank vessel" for
spills of oil on or above the water surface, with liability limits of $1,200 per
gross ton or $10.0 million. To the extent damages and removal costs exceed this
amount, the mobile offshore drilling rig will be treated as an offshore facility
and the offshore lessee will be responsible up to higher liability limits for
all removal costs plus $75.0 million. A party cannot take advantage of liability
limits if the spill was caused by gross negligence or willful misconduct or
resulted from violation of a federal safety, construction or operating
regulation. If the party fails to report a spill or to cooperate fully in the
cleanup, liability limits likewise do not apply. Few defenses exist to the
liability imposed by the OPA. The OPA also imposes ongoing requirements on a
responsible party, including proof of financial responsibility (to cover at
least some costs in a potential spill) and preparation of an oil spill
contingency plan for offshore facilities and vessels in excess of 300 gross
tons. Amendments to the OPA adopted in 1996 require owners and operators of
offshore facilities that have a worst case oil spill potential of more than
1,000 barrels to demonstrate financial responsibility in amounts ranging from
$10.0 million in specified state waters to $35.0 million in federal Outer
Continental Shelf waters, with higher amounts, up to $150.0 million, in certain
limited circumstances where the U.S. Minerals Management Service ("MMS")
believes such a level is justified by the risks posed by the quantity or quality
of oil that is handled by the facility. However, such OPA amendments did not
reduce the amount of financial responsibility required for "tank vessels." Since
the Company's offshore drilling rigs are typically classified as tank vessels,
the recent amendments to the OPA are not expected to have a significant effect
on the Company's operations. A failure to comply with ongoing requirements or
inadequate cooperation in a spill may even subject a responsible party to civil
or criminal enforcement actions.
In addition, the OCSLA authorizes regulations relating to safety and
environmental protection applicable to lessees and permittees operating on the
Outer Continental Shelf. Specific design and operational standards may apply to
Outer Continental Shelf vessels, rigs, platforms, vehicles and structures.
Violations of environmental-related lease conditions or regulations issued
pursuant to the OCSLA can result in substantial civil and criminal penalties as
well as potential court injunctions curtailing operations and the cancellation
of leases. Such enforcement liabilities can result from either governmental or
citizen prosecution.
All of the Company's operating U.S. barge drilling rigs have zero
discharge capabilities as required by law. In addition, in recognition of
environmental concerns regarding dredging of inland waters and permitting
requirements, the Company conducts negligible dredging operations, with
approximately two-thirds of the Company's offshore drilling contracts involving
directional drilling, which minimizes the need for dredging. However, the
existence of such laws and regulations has had and will continue to have a
restrictive effect on the Company and its customers.
7
CERCLA, also known as "Superfund," and comparable state laws impose
liability without regard to fault or the legality of the original conduct, on
certain classes of persons who are considered to be responsible for the release
of a "hazardous substance" into the environment. While CERCLA exempts crude oil
from the definition of hazardous substances for purposes of the statute, the
Company's 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. The
Company believes that it is in compliance with CERCLA and currently is not aware
of any events that, if brought to the attention of regulatory authorities, would
lead to the imposition of CERCLA liability against the Company.
RCRA generally does not regulate most wastes generated by the exploration
and production of oil and gas. RCRA specifically excludes from the definition of
hazardous waste "drilling fluids, produced waters, and other wastes associated
with the exploration, development, or production of crude oil, natural gas or
geothermal energy." However, these wastes may be regulated by EPA or state
agencies as solid waste. Moreover, ordinary industrial wastes, such as paint
wastes, waste solvents, laboratory wastes, and waste oils, may be regulated as
hazardous waste. Although the costs of managing solid and hazardous wastes may
be significant, the Company does not expect to experience more burdensome costs
than similarly situated companies involved in drilling operations in the Gulf
Coast market.
The drilling industry is dependent on the demand for services from the oil
and gas exploration and development industry, and accordingly, is affected by
changes in laws relating to the energy business. The Company's business is
affected generally by political developments and by federal, state, local and
foreign regulations that may relate directly to the oil and gas industry. The
adoption of laws and regulations, both U.S. and foreign, that curtail
exploration and development drilling for oil and gas for economic, environmental
and other policy reasons may adversely affect the Company's operations by
limiting available drilling opportunities.
8
FINANCIAL INFORMATION ABOUT INDUSTRY SEGMENTS
The Company operates in three segments, U.S. drilling services,
international drilling services and rental tool operations. Information about
the Company's business segments and operations by geographic areas for the years
ended December 31, 2001, 2000 and 1999 is set forth in Note 9 in the notes to
consolidated financial statements.
Item 2. PROPERTIES
The Company leases office space in Houston for its corporate headquarters.
Additionally, the Company owns and leases office space and operating facilities
in various locations, but only to the extent necessary for administrative and
operational support functions. The Company owns a ten-story building in Tulsa,
Oklahoma, the previous corporate headquarters which is vacant and held for sale.
Land Rigs. The following table shows, as of December 31, 2001, the
locations and drilling depth ratings of the Company's 41 actively marketed land
rigs:
Drilling Depth Rating in Feet
-----------------------------------------
10,000 10,000
or to Over
International less 25,000 25,000 Total
------------- ---- ------ ------ -----
Actively marketed land rigs:
Latin America -- 11 7 18
Asia Pacific/Middle East/Africa 2 12 -- 14
Former Soviet Union 2 4 3 9
-- -- -- --
Total 4 27 10 41
== == == ==
In addition, the Company has seven land rigs classified as cold stacked
which would need to be refurbished at a significant cost before being placed
back into service, with locations and drilling depth ratings as follows:
Drilling Depth Rating in Feet
-----------------------------------------
10,000 10,000
or to Over
International less 25,000 25,000 Total
------------- ---- ------ ------ -----
Cold stacked land rigs:
Latin America -- 1 -- 1
Asia Pacific/Middle East/Africa 3 3 -- 6
Former Soviet Union -- -- -- --
-- -- -- --
Total 3 4 -- 7
== == == ==
9
Barge Rigs. A schedule of the Company's deep, intermediate and workover
and shallow drilling barge rigs located in the Gulf of Mexico, as of December
31, 2001, is set forth below:
Year Built Maximum
or Last Drilling
Gulf of Mexico Horsepower Refurbished Depth (Feet) Status (1)
-------------- ---------- ----------- ------------ ----------
Deep drilling:
Rig No. 15 1,000 1998 15,000 Active
Rig No. 50 2,000 2001 25,000 Active
Rig No. 51 2,000 1993 25,000 Active
Rig No. 53 1,600 1995 20,000 Active
Rig No. 54 2,000 1995 25,000 Active
Rig No. 55 2,000 2001 25,000 Active
Rig No. 56 2,000 1992 25,000 Active
Rig No. 57 1,500 1997 20,000 Active
Rig No. 76 3,000 1997 30,000 Active
Intermediate drilling:
Rig No 8 1,000 1995 14,000 Active
Rig No. 17 1,000 1993 13,000 Active
Rig No. 20 1,000 2001 12,500 Active
Rig No. 21 1,200 2001 13,000 Active
Rig No. 23 1,000 1993 11,500 Active
Workover and shallow drilling:
Rig No. 6 (2) 700 1995 -- Active
Rig No. 9 (2) 650 1996 -- Active
Rig No. 12 1,100 1990 14,000 Active
Rig No. 16 800 1994 8,500 Active
Rig No. 18 800 1993 8,500 Active
Rig No. 24 1,000 1992 11,500 Active
Rig No. 25 1,000 1993 11,500 Active
Rig No. 26 (2) 650 1996 -- Active
(1) "Active" denotes that the rig is currently under contract or
available for contract.
(2) Workover rig.
10
A schedule of the Company's international drilling barges, as of December
31, 2001, is set forth below:
Year Built Maximum
or Last Drilling
International Horsepower Refurbished Depth (Feet) Status (1)
------------- ---------- ----------- ------------ ----------
Deep drilling:
Rig No. 72 3,000 1991 30,000 Active
Rig No. 73 3,000 2000 30,000 Active
Rig No. 74 3,000 1997 30,000 Active
Rig No. 75 3,000 1999 30,000 Active
Rig No. 257 3,000 1999 25,000 Active
(1) "Active" denotes that the rig is currently under contract or
available for contract.
Platform Rigs. The following table sets forth certain information, as of
December 31, 2001, with respect to the Company's platform rigs:
Year Built Maximum
or Last Drilling
Gulf of Mexico Horsepower Refurbished Depth (Feet) Status (1)
-------------- ---------- ----------- ------------ ----------
Platform rigs:
Rig No. 2 1,000 1982 12,000 Active
Rig No. 3 1,000 1997 12,000 Active
Rig No. 10 (2) 650 1989 -- Active
Rig No. 41 1,000 1997 12,500 Active
(1) "Active" denotes that the rig is currently under contract or
available for contract.
(2) Workover rig.
11
Jackup Rigs. The following table sets forth certain information as of
December 31, 2001, with respect to the Company's jackup rigs:
Maximum Maximum
Water Drilling
Gulf of Mexico Design (1) Depth (Feet) Depth (Feet) Status (2)
-------------- ---------- ----------- ------------ ----------
Jackup rigs:
Rig No. 11 (3) Bethlehem JU-200 (MC) 200 -- Active
Rig No. 14 Baker Marine Big Foot (IS) 85 20,000 Active
Rig No. 15 Baker Marine Big Foot III (IS) 100 20,000 Active
Rig No. 20 Bethlehem JU-100 (MC) 110 25,000 Active
Rig No. 21 Baker Marine BMC-125 (MC) 100 20,000 Active
Rig No. 22 Le Tourneau Class 51 (MC) 173 15,000 Active
Rig No. 25 Le Tourneau Class 150-44 (IC) 215 20,000 Active
(1) IC--independent leg, cantilevered; IS--independent leg, slot;
MC--mat-supported, cantilevered.
(2) "Active" denotes that the rig is currently under contract or
available for contract.
(3) Workover rig.
12
The following table presents the Company's utilization rates, rigs
available for service and cold stacked rigs.
Year Ended December 31,
---------------------------------
Transition Zone Rig Data 2001 2000
- ---------------------------------------------------------- --------------- ---------------
U.S. barge deep drilling:
Rigs available for service (1) 9.0 8.0
Utilization rate of rigs available for service (2) 93% 92%
U.S. barge intermediate drilling:
Rigs available for service (1) 5.0 5.0
Utilization rate of rigs available for service (2) 80% 93%
U.S. barge workover and shallow drilling:
Rigs available for service (1) 8.0 9.0
Utilization rate of rigs available for service (2) 53% 44%
International barge drilling:
Rigs available for service (1) 5.0 5.0
Utilization rate of rigs available for service (2) 97% 97%
Offshore Rig Data
- ----------------------------------------------------------
Jackup rigs:
Rigs available for service (1) 7.0 7.0
Utilization rate of rigs available for service (2) 78% 86%
Platform rigs:
Rigs available for service (1) 4.0 4.0
Utilization rate of rigs available for service (2) 47% 53%
Year Ended December 31,
---------------------------------
Land Rig Data 2001 2000
- ---------------------------------------------------------- --------------- ---------------
International rigs:
Rigs available for service (1) 41.0 40.0
Utilization rate of rigs available for service (2) 49% 35%
Cold stacked rigs (1) 7.0 7.0
U.S. rigs: (3)
Rigs available for service (1) -- 0.9
Utilization rate of rigs available for service (2) -- 0%
13
(1) The number of rigs is determined by calculating the number of days
each rig was in the fleet, e.g., a rig under contract or available
for contract for an entire year is 1.0 "rigs available for service"
and a rig cold stacked for one quarter is 0.25 "cold stacked rigs."
"Rigs available for service" includes rigs currently under contract
or available for contract. "Cold stacked rigs" includes all rigs
that are stacked and would require significant refurbishment cost
before being placed back into service.
(2) Rig utilization rates are based on a weighted average basis assuming
365 days availability for all rigs available for service. Rigs
acquired or disposed of have been treated as added to or removed
from the rig fleet as of the date of acquisition or disposal. Rigs
that are in operation or fully or partially staffed and on a
revenue-producing standby status are considered to be utilized. Rigs
under contract that generate revenues during moves between locations
or during mobilization/demobilization are also considered to be
utilized.
(3) Includes one U.S. land rig located in Alaska, through the date of
sale November 20, 2000.
Item 3. LEGAL PROCEEDINGS
Verdin Lawsuit. Two subsidiaries of Parker Drilling Company
("Subsidiaries") are currently named defendants in the lawsuit, Verdin vs. R & B
Falcon Drilling USA, Inc., et. al., Civil Action No. G-00-488, currently pending
in the U.S. District Court for the Southern District of Texas, Houston Division.
The plaintiff is a former employee of a drilling contractor engaged in offshore
drilling operations in the Gulf of Mexico. The defendants are various drilling
contractors, including the Subsidiaries, who conduct drilling operations in the
Gulf of Mexico. Plaintiff alleges that the defendants have violated federal and
state antitrust laws by agreeing with each other to depress wages and benefits
paid to employees working for said defendants.
Plaintiff is seeking to bring this case as a "class action", i.e., on
behalf of himself and a proposed class of other similarly situated employees of
the defendants that have allegedly suffered similar damages from the alleged
actions of defendants. Originally, the case was pending in U.S. District Court
for the Southern District of Texas, Galveston Division. The case was
subsequently transferred to the Houston Division. The subsidiaries and certain
of the other defendants recently entered into a stipulation of settlement with
the plaintiff, pursuant to which the subsidiaries will pay $625,000 for a full
and complete release of all claims brought in the case. The settlement was
preliminarily approved by the Court on November 8, 2001, and the Court will
conduct a fairness hearing on April 18, 2002 to determine whether the proposed
settlements should receive final approval. The settlement amount and related
fees were accrued during the third quarter 2001.
Kazakhstan tax issue. On July 6, 2001, the Ministry of State Revenues of
Kazakhstan ("MSR") issued an Act of Audit to the Kazakhstan branch ("PKD
Kazakhstan") of Parker Drilling Company International Limited, a wholly-owned
subsidiary of the Company ("PDCIL"), assessing additional taxes in the amount of
approximately $29,000,000 for the years 1998 through 2000. The assessment
consists primarily of adjustments in corporate income tax based on a
determination by the Kazakhstan tax authorities that payments by Offshore
Kazakhstan International Operating Company, ("OKIOC"), to PDCIL of $99,050,000,
in reimbursement of costs for modifications to Rig 257, performed by PDCIL prior
to the importation of the drilling rig into Kazakhstan, where it is currently
working under contract to OKIOC, are income to PKD Kazakhstan, and therefore,
taxable to PKD Kazakhstan. PKD Kazakhstan filed an Act of Non-Agreement stating
its position that such payment should not be taxable and requesting the Act of
Audit be revised accordingly. In November, the MSR rejected PKD Kazakhstan's Act
of Non-Agreement, prompting PKD Kazakhstan to seek judicial review of the
assessment. On December 28, 2001, the Astana City Court issued a judgment in
14
favor of PKD Kazakhstan, finding that the reimbursements to PDCIL were not
income to PKD Kazakhstan and not otherwise subject to tax based on the
US-Kazakhstan Tax Treaty. The MSR has appealed the Astana City Court decision to
the Supreme Court, but has requested and received a postponement in the hearing
until March 21, 2002. Management believes that it is still not possible to make
a reasonable determination as to the probable outcome of this matter. Should PKD
Kazakhstan be required to pay the full assessment, the Company has sufficient
cash on hand to make the payment.
The Company is a party to certain legal proceedings that have resulted
from the ordinary conduct of its business. In the opinion of the Company's
management, none of these proceedings is expected to have a material adverse
effect on the Company.
Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
There were no matters submitted to Parker Drilling Company security
holders during the fourth quarter of 2001.
Item 4A. EXECUTIVE OFFICERS
Officers are elected each year by the board of directors following the
annual meeting for a term of one year and until the election and qualification
of their successors. The current executive officers of the Company and their
ages, positions with the Company and business experience are presented below:
(1) Robert L. Parker, 78, chairman, joined the Company in 1944 and was
elected vice president in 1950. He was elected president in 1954 and
chief executive officer and chairman in 1969. Since 1991, he has
held only the position of chairman.
(2) Robert L. Parker Jr., 53, president and chief executive officer,
joined the Company in 1973 as a contract representative and was
named manager of U.S. operations later in 1973. He was elected a
vice president in 1973, executive vice president in 1976 and was
named president and chief operating officer in October 1977. In
December 1991, he was elected chief executive officer.
(3) James J. Davis, 55, senior vice president of finance and chief
financial officer, joined the Company in November 1991. From 1986
through 1991, Mr. Davis was vice president and treasurer of MAPCO
Inc., a diversified energy company with interests in natural gas
liquids marketing and transportation, oil refining and retail motor
fuel marketing. He serves as a member of the board of directors of
Dollar Thrifty Funding Corp.
(4) Robert F. Nash, 58, senior vice president and chief operating
officer, joined the Company in November 2001. Mr. Nash joined the
Company following a 26-year career with Halliburton, during which
time he held numerous senior management positions with
responsibility for operations, technical development, manufacturing,
procurement, inventory management and sales and marketing. He also
has considerable experience with mergers, acquisitions, divestitures
and reorganizations.
(5) Thomas L. Wingerter, 49, vice president of operations, joined the
Company in 1979. In 1983 he was named contract manager for the Rocky
Mountain division. He was promoted to Rocky Mountain division
manager in 1984, a position he held until September 1991 when he was
elected vice president, North American region. In March 1999 he was
appointed vice president and general manager - North American
operations. In January 2001, he was appointed to his current
position.
15
(6) W. Kirk Brassfield, 46, vice president and corporate controller
joined the Company in March 1998 as corporate controller and chief
accounting officer. From 1991 through March 1998, Mr. Brassfield
served in various positions, including subsidiary controller and
director of financial planning of MAPCO Inc., a diversified energy
company. From 1979 through 1991, Mr. Brassfield served at the public
accounting firm, KPMG Peat Marwick.
OTHER PARKER DRILLING COMPANY OFFICERS
(7) John R. Gass, 50, vice president of corporate business development,
joined the Company in 1977 and has served in various management
positions in the Company's international divisions. In 1985 he
became the division manager of Africa and the Middle East. In 1987
he directed the Company's core drilling operations in South Africa.
In 1989 he was promoted to international contract manager. In
January 1996, he was elected vice president, frontier areas and
assumed his current position in March 1999.
(8) Denis Graham, 52, vice president of engineering, joined the Company
in 2000. Mr. Graham was the senior vice president of technical
services for Diamond Offshore Inc., an international offshore
drilling contractor. His experience with Diamond Offshore ranged
from 1978 through 1999 in the areas of offshore drilling rig design,
new construction, conversions, marine operations, maintenance and
regulatory compliance.
(9) Patrick Seals, 38, vice president of shared services, joined the
Company in 1992 as an internal auditor. From 1993 through 1999, he
held various contracts and marketing management roles in the North
American Division. In late 1999, Mr. Seals assumed the role of
general manager of e-business and in January of 2001 was promoted to
his current position. From 1985 to 1992, he served in roles at the
public accounting firm of Arthur Andersen, Scrivner, Inc. and The
Oklahoma Publishing Company.
(10) David W. Tucker, 46, was elected treasurer in March 1999. He joined
the Company in 1978 as a financial analyst and served in various
financial and accounting positions before being named chief
financial officer of the Company's wholly-owned subsidiary, Hercules
Offshore Corporation, in February 1998.
16
PART II
Item 5. MARKET FOR REGISTRANT'S COMMON STOCK AND RELATED STOCKHOLDER MATTERS
Parker Drilling Company common stock is listed for trading on the New York
Stock Exchange under the symbol PKD. At the close of business on December 31,
2001, there were 3,004 holders of record of Parker Drilling common stock. Prices
on Parker Drilling's common stock for the years ended December 31, 2001 and
2000, were as follows:
2001 2000
------------------ ---------------------
Quarter High Low High Low
- ------------- ---- --- ---- ---
First $7.53 $4.75 $5.125 $3.000
Second 7.40 5.21 6.875 3.750
Third 6.29 2.25 7.438 4.875
Fourth 4.07 2.56 7.125 3.938
No dividends have been paid on common stock since February 1987.
Restrictions contained in Parker Drilling's existing bank revolving loan
facility prohibit the payment of dividends and the indenture for the Senior
Notes restricts the payment of dividends. The Company has no present intention
to pay dividends on its common stock in the foreseeable future because of the
restrictions noted.
17
Item 6. SELECTED FINANCIAL DATA (Dollars in Thousands Except Per Share Data)
Four Months
Year Ended Year Ended Year Ended Ended
December 31, December 31, December 31, December 31,
2001 2000 1999 1998
------------ ------------ ------------ ------------
Revenues $ 487,965 $ 376,349 $ 324,553 $ 136,723
Net income (loss) $ 11,059 $ (19,045)(1) $ (37,897) $ (14,633)
Diluted earnings (loss) per share 0.12 $ (0.23)(1) $ (0.49) $ (0.19)
Total assets $1,105,777 $1,107,419 $1,082,743 $1,159,326
Long-term debt $ 587,165 $ 592,584 $ 648,577 $ 630,479
Year Ended Year Ended
August 31, August 31,
1998 1997
---------- ----------
Revenues $ 481,223 $311,644
Net income $ 28,092 $ 16,315
Diluted earnings per share $ 0.36 $ 0.23
Total assets $1,200,544 $984,136
Long-term debt $ 630,090 $551,042
(1) Loss before extraordinary gain was $(22,981) or $(0.28) per share.
18
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
RESULTS OF OPERATIONS
Outlook and Overview
The year 2001 was marked by an overall improvement in rig activity and
cash flow for the Company. Net income improved to $11.1 million as compared to
net losses before extraordinary gain of $23.0 million and $37.9 million the
previous two years. Rig utilization, dayrates and rental activity improved
substantially in the Company's Gulf of Mexico drilling markets, continuing a
trend that started in mid-2000. The main driver of this trend was the increase
in spending by oil and gas operators in response to significantly higher demand
and prices for natural gas in the United States. The Company's international
markets began to improve late in 2001 experiencing significantly higher
utilization in the fourth quarter, most notably in the Asia Pacific region and
Kazakhstan.
After reaching the highest levels of dayrates and utilization since fall
of 1998, the Gulf of Mexico market began to soften at the end of the third
quarter of 2001 due primarily to a reduction in drilling activity by operators
in response to declining demand and prices for natural gas, due in part to the
economic recession in the United States. During the fourth quarter, dayrates for
the Company's seven jackup rigs dropped approximately 25 percent while
utilization decreased from 87 percent for the first three quarters to 52 percent
for the fourth quarter. During the same period, some softness was experienced in
the Company's Gulf of Mexico rental tool operations and barge rig business, but
to a much lesser extent than the jackup rigs due to the consolidated nature of
the barge rig market. Management anticipates that the reduced demand for
drilling services in the Gulf of Mexico market will continue through the first
half of 2002, which will result in reduced revenues from our barge, jackup and
rental tools operations as compared to 2001. Management anticipates that
revenues from the Company's international land rig operations will increase over
2001, due to increased rig utilization in our markets, particularly Latin
America and the Asia Pacific region. International barge revenues for 2002 are
anticipated to approximate 2001.
In the Company's fourth quarter conference call with investors, management
stated that the level of revenues and cash flow that the Company will generate
in 2002 will depend to a large extent on the pace of recovery in drilling
activity and dayrates in the Gulf of Mexico market. Management anticipates that
drilling activity will increase in the second half of 2002 if there is a
sustained recovery in the U.S. economy, which would reduce current high
inventories and lead to an increase in demand for natural gas. One scenario
posed by management to investors is for a fairly rapid pickup in rig utilization
and rental tool activity, in which case revenues for the year 2002 could reach
$480 million. This compares with revenues for the year 2001 of $488.0 million.
On the other hand, if the recovery in the U.S. economy lags and the demand for
natural gas is not as strong, then the recovery in the Gulf of Mexico market
could lag until the third quarter. In this case management anticipates revenues
could be approximately $450 million.
During September 2001, the Company relocated its corporate office to
Houston. The reorganization included the consolidation of its corporate and
international drilling activities from Tulsa, Oklahoma, with its U.S. offshore
drilling operations already domiciled in Houston. The reorganization of certain
senior management positions and management of drilling operations accompanied
the relocation. Management believes that the Company will benefit from being
closer to its customers, competitors and vendors and anticipates increased
operational efficiency from the consolidation of its operations and
administrative functions. The total non-recurring expense for the move of the
corporate office to Houston approximated $7.5 million.
19
RESULTS OF OPERATIONS (continued)
Year Ended December 31, 2001 Compared to Year Ended December 31, 2000
The Company recorded net income of $11.1 million, for the year ended
December 31, 2001, compared to a net loss of $23.0 million, before extraordinary
gain, recorded for the year ended December 31, 2000.
Year Ended December 31,
-----------------------------------------
2001 2000
----------------- -----------------
Revenues: (Dollars in Thousands)
U.S. drilling $190,809 39% $148,416 40%
International drilling 231,527 48% 185,100 49%
Rental tools 65,629 13% 42,833 11%
-------- --- -------- ---
Total revenues $487,965 100% $376,349 100%
======== === ======== ===
The Company's revenues increased $111.6 million to $488.0 million in the
current year as compared to 2000. U.S. offshore drilling revenues increased
$44.1 million to $190.8 million due primarily to increased dayrates for the
drilling barge rigs and the jackup rigs. Dayrates increased 32 percent and 40
percent for the barge rigs and jackup rigs, respectively, as compared to the
previous year. The increase in dayrates was partially offset by decreased
utilization from 86 percent in 2000 to 78 percent in 2001 for the jackup rigs.
The decrease in utilization was due primarily to the slowdown in the Gulf of
Mexico jackup market during the fourth quarter of 2001. Jackup utilization
during the fourth quarter was 52 percent as compared to approximately 87 percent
during the first three quarters of 2001. U.S. land drilling revenues decreased
$1.7 million due to the sale of the Company's last remaining U.S. land rig, Rig
245, in November 2000.
International drilling revenues increased $46.4 million to $231.5 million
in the current period as compared to the year ended December 31, 2000.
International land drilling revenues increased $38.5 million to $151.5 million
during 2001. Revenues in the Former Soviet Union region, which includes
Kazakhstan and Russia, increased $32.3 million to $63.1 million during 2001 as
compared to the previous year. Kazakhstan increased $30.0 million as one rig was
added to the Tengiz operation and three rigs were added to the Karachaganak
joint venture with Saipem. Russia increased by $2.3 million as one rig commenced
operations during 2001. Revenues increased $10.7 million in the Asia Pacific
region due primarily to increased rig utilization in Indonesia, Papua New Guinea
and New Zealand. Offsetting these increases were decreases in revenues from
Madagascar and Nigeria's land rig due to completion of drilling contracts in
these countries in 2000. Revenues in the Latin America region decreased $4.4
million to $54.1 million during 2001. Revenues in Bolivia decreased $12.1
million during 2001 due primarily to an oversupply of natural gas in Bolivia
resulting in a significant decrease in rig utilization. Partially offsetting the
decrease in Bolivia was an increase in revenues of $8.7 million in Colombia.
During 2001 rig utilization increased in Colombia to 92 percent from 83 percent
in 2000, and currently the Company has six rigs working in Colombia.
International offshore drilling revenues increased $7.9 million to $80.0
million during 2001. Revenues in the Caspian Sea (barge Rig 257) decreased by
$1.6 million while revenues in Nigeria increased $9.5 million. Barge Rig 257
revenues decreased primarily due to reduced rates received during the lengthy
rig move after completion of the first well. Revenues for the four barge rigs in
Nigeria improved due to increased drilling operations on full dayrates. Last
year the rigs were on reduced standby rates for approximately six months due to
several episodes of community unrest.
20
RESULTS OF OPERATIONS (continued)
Rental tool revenues increased $22.8 million due to the increased level of
drilling activity in the Gulf of Mexico. Contributing to this increase was the
New Iberia, Louisiana, operation in the amount of $10.3 million, $6.3 million
from the Victoria, Texas, operation and $6.2 million from the Odessa, Texas,
operation which commenced operations in May 2000.
Year Ended December 31,
--------------------------------------
2001 2000
---------------- ----------------
Profit margin: (Dollars in Thousands)
U.S. drilling $ 78,329 41% $ 49,219 33%
International drilling 77,043 33% 52,218 28%
Rental tools 42,624 65% 26,839 63%
-------- -- -------- --
Total profit margin 197,996 41% 128,276 34%
-------- -- -------- --
Depreciation and amortization 97,259 85,060
General and administration 21,721 20,392
Other 7,500 8,300
-------- --------
Operating income $ 71,516 $ 14,524
======== ========
(Profit margin - revenues less direct operating expenses; profit margin
percentages - profit margin as a percent of revenues.)
Profit margin of $198.0 million in the current period reflects an increase
of $69.7 million from the $128.3 million recognized during the year ended
December 31, 2000. The U.S. and international drilling segments recorded profit
margin percentages of 41 percent and 33 percent, respectively, in the current
year, as compared to 33 percent and 28 percent in 2000. U.S. profit margins
increased $29.1 million. U.S. drilling profit margin was positively impacted
during the current year by increasing dayrates in the Gulf of Mexico from the
barge and jackup rigs. Average dayrates for the barge rigs and jackup rigs
increased approximately 31 percent and 42 percent, respectively, during the
current period when compared to the prior year. Jackup rig utilization decreased
from 86 percent in 2000 to 78 percent in 2001 due primarily to a slowdown in the
Gulf of Mexico jackup market during the fourth quarter, which resulted in jackup
rig utilization of 52 percent. This slowdown negatively impacted jackup rig
dayrates, which declined approximately 23 percent from the first three quarters
of 2001.
International drilling profit margin increased $24.8 million to $77.0
million during the year ended December 31, 2001 as compared to 2000.
International land drilling profit margin increased $18.1 million to $47.6
million. Profit margin for the international land drilling operations increased
in Kazakhstan from 33 percent to 45 percent, Papua New Guinea from 27 percent to
48 percent, and New Zealand from 20 percent to 39 percent, primarily due to
higher utilization during 2001. Profit margin in Russia decreased $5.4 million
due to higher than anticipated mobilization and start up costs. The
international offshore drilling profit margin increased $6.7 million to $29.5
million, with profit margin increasing from 32 percent to 37 percent during 2001
as compared to 2000.
Rental tool profit margin increased $15.8 million to $42.6 million during
the current year as compared to the year ended December 31, 2000. Profit margin
increased primarily due to the $22.8 million increase in revenues during the
current year. The profit margin percentage increased during the current period
to 65 percent from 63 percent for the previous year due principally to higher
revenues without a corresponding increase in fixed cost.
21
RESULTS OF OPERATIONS (continued)
Depreciation and amortization expense increased $12.2 million to $97.3
million in the current year. Depreciation expense recorded in connection with
capital additions for the years 1999, 2000 and 2001, was the primary reason for
the increase. General and administrative expenses increased $1.3 million in the
current year as compared to 2000. This increase is primarily attributed to
increased travel costs, professional fees, information technology projects, and
higher occupancy costs associated with the new corporate office in Houston.
The Company recognized $7.5 million in reorganization costs, which
includes employee moving expenses and severance costs, during 2001. In September
2001, the Company opened its new corporate office in Houston. The reorganization
included the consolidation of its corporate and international drilling
activities from Tulsa, Oklahoma, with its U.S. offshore drilling operations
already domiciled in Houston. The relocation was accompanied by the
reorganization of certain senior management positions and the management of
drilling operations.
Interest expense decreased $4.0 million due to the $50.5 million repayment
of convertible notes during the fourth quarter of 2000 and $1.6 million of
interest being capitalized to construction projects during the year ended
December 31, 2001, as compared to $0.5 million capitalized during the prior
year. Gain on disposition of assets decreased $15.6 million to $2.3 million for
the current year. During the year 2000, the Company sold its one million shares
of Unit Corporation common stock and recognized a pre-tax gain of $7.4 million
and the Company sold Rig 245 in Alaska for $20.0 million and recognized a
pre-tax gain of $14.9 million.
Income tax expense consists of foreign tax expense of $14.0 million and
deferred tax benefit of $1.4 million. The deferred tax benefit is due to the
reduction in the valuation allowance of $9.6 million offsetting deferred tax
expense of $8.2 million. The reduction was the result of a change in estimate
relating to the realization of net operating loss carryforwards (NOL's). At
December 31, 2000, the Company carried a valuation account reserving part of the
NOL's set to expire during the tax year ended August 31, 2001. Due to higher
than projected taxable income for the 2001 tax year, the Company utilized more
NOL's than originally anticipated resulting in the deferred tax benefit. As of
December 31, 2001, the remaining valuation allowance is $9.9 million. For
additional information, see Note 5 in the notes to consolidated financial
statements.
22
RESULTS OF OPERATIONS (continued)
Year Ended December 31, 2000 Compared to Year Ended December 31, 1999
The Company recorded a net loss of $23.0 million, before extraordinary
gain, for the year ended December 31, 2000, compared to a net loss of $37.9
million recorded for the year ended December 31, 1999.
Year Ended December 31,
-----------------------------------------
2000 1999
----------------- -----------------
Revenues: (Dollars in Thousands)
U.S. drilling $148,416 40% $113,989 35%
International drilling 185,100 49% 182,908 56%
Rental tools 42,833 11% 27,656 9%
-------- --- -------- ---
Total revenues $376,349 100% $324,553 100%
======== === ======== ===
The Company's revenues increased $51.8 million to $376.3 million in 2000
as compared to 1999. U.S. drilling revenues increased $34.4 million to $148.4
million. U.S. offshore drilling revenues increased $50.5 million due primarily
to increased utilization and dayrates for the drilling barge rigs and the jackup
rigs. U.S. land drilling revenues decreased $16.1 million due to the sale of the
Company's 13 U.S. land rigs on September 30, 1999 and the sale of Rig 245,
located in Alaska, in November 2000. Rig 245 was stacked throughout 2000.
International drilling revenues increased $2.2 million to $185.1 million
in 2000 as compared 1999. International land drilling revenues decreased $14.5
million while international offshore drilling revenues increased $16.7 million.
Primarily responsible for the international land drilling revenues decrease was
the Latin America region, which decreased $15.9 million. This decrease is
attributed to reduced rig utilization in Colombia, Ecuador and Peru. Revenues
from the Bolivian operations were relatively constant for the two periods but
began to fall during the fourth quarter of 2000. In addition, land drilling
revenues decreased $9.7 million in the Asia Pacific region due to completion of
a one-well drilling contract in Vietnam that ended during the third quarter of
1999, and reduced utilization in Papua New Guinea. Revenues in the Frontier
region, which includes Russia, Kazakhstan, Africa and the Middle East, increased
$11.1 million during 2000 as compared to the year ended December 31, 1999. This
increase is primarily attributed to short-term drilling contracts conducted in
2000 in Madagascar and Nigeria (land contract). Additionally, a labor contract
in Kuwait and increased in rig utilization in Kazakhstan contributed to the
increase.
International offshore drilling revenues increased $16.7 million to $72.2
million due primarily to barge Rig 257 in the Caspian Sea and barge Rig 75 in
Nigeria. Barge Rig 257, which commenced drilling in September of 1999,
contributed $24.8 million of revenues during the year ended December 31, 2000,
an increase of $16.2 million. With the addition of barge Rig 75 during the third
quarter of 1999, the Company had four barge rigs in the Nigerian offshore
market. Due to several episodes of community unrest, three of the four barge
rigs were on standby status during most of the first six months of 2000. One
rig, barge Rig 74, operated for approximately three and a half months during the
first six months. Despite the reduced revenues earned while on standby, Nigerian
offshore revenues increased $11.3 million to $47.4 million during 2000. The
increase is due to revenues earned by the new barge Rig 75 and the start-up of
drilling operations on Rig 74, which was on standby during 1999. During the last
five months of 2000, drilling operations on the Nigerian barge rigs were at full
dayrates. Offsetting the increased revenues in the Caspian Sea and Nigeria was a
$10.8 million decrease in international offshore revenues due to the completion
of a barge contract in Venezuela during the third quarter of 1999.
23
RESULTS OF OPERATIONS (continued)
Rental tool revenues increased $15.2 million due to the increased level of
drilling activity in the Gulf of Mexico. Contributing to this increase was the
New Iberia, Louisiana, operation in the amount of $7.7 million, $5.0 million
from the Victoria, Texas, operation and $2.5 million from the Odessa, Texas,
operation which commenced operations in May 2000.
Year Ended December 31,
--------------------------------------
2000 1999
---------------- ----------------
Profit margin: (Dollars in Thousands)
U.S. drilling $ 49,219 33% $ 11,891 10%
International drilling 52,218 28% 56,682 31%
Rental tools 26,839 63% 16,746 61%
-------- -- -------- --
Total profit margin 128,276 34% 85,319 26%
-------- -- -------- --
Depreciation and amortization 85,060 82,170
General and administration 20,392 16,312
Other 8,300 13,607
-------- --------
Operating income (loss) $ 14,524 $(26,770)
======== =========
(Profit margin - revenues less direct operating expenses; profit margin
percentages - profit margin as a percent of revenues.)
Profit margin of $128.3 million in 2000 reflect an increase of $43.0
million from the $85.3 million recorded during 1999. The U.S. and international
drilling segments recorded profit margin percentages of 33 percent and 28
percent, respectively, during the year ended December 31, 2000, as compared to
10 percent and 31 percent in 1999. U.S. profit margin increased $37.3 million.
U.S. drilling profit margin was positively impacted during 2000 by increased
utilization in the Gulf of Mexico from the barge and jackup rigs. In addition,
average dayrates for the jackup rigs increased approximately 45 percent during
2000 when compared to 1999. Offsetting the increased U.S. offshore profit margin
was the sale of all 13 U.S. lower-48 land rigs during the third quarter of 1999.
During the year ended December 31, 1999, the U.S. lower-48 land rigs contributed
profit margin of $1.7 million. In addition, Rig 245, which was stacked in Alaska
all year, was sold in November of 2000.
International drilling profit margin declined $4.5 million to $52.2
million during the year ended December 31, 2000 as compared to 1999.
International land drilling profit margin declined $5.8 million to $29.5 million
during 2000 primarily due to lower utilization in the Company's land drilling
operations as previously discussed. The international offshore drilling profit
margin increased $1.3 million to $22.7 million.
Rental tool profit margin increased $10.1 million to $26.8 million during
2000 as compared to the year ended December 31, 1999. Profit margin increased
primarily due to the $15.2 million increase in revenues during 2000. The profit
margin percentage increased during 2000 to 63 percent from 61 percent for 1999.
Depreciation and amortization expense increased $2.9 million to $85.1
million during 2000. Depreciation expense recorded in connection with 1998 and
1999 capital additions, principally barge Rig 257 and barge Rig 75, was the
primary reason for the increase. General and administrative expenses increased
$4.1 million during 2000 as compared to 1999. This increase is primarily
attributed to travel costs, employee bonuses, franchise taxes, professional fees
and information technology projects.
24
RESULTS OF OPERATIONS (continued)
Interest expense increased $1.1 million due to $3.0 million of interest
being capitalized to construction projects during the year ended December 31,
1999, as compared to $0.5 million capitalized during 2000. Gain on disposition
of assets decreased $21.2 million to $17.9 million for the year ended December
31, 2000. On September 30, 1999 the Company sold its U.S. lower-48 land rigs to
Unit Corporation for $40.0 million cash plus one million shares of Unit
Corporation common stock. The Company recognized a pre-tax gain of $36.1 million
during the third quarter of 1999. In September 2000, the Company sold its one
million shares of Unit Corporation common stock and recognized a pre-tax gain of
$7.4 million. In November 2000, the Company sold Rig 245 in Alaska for $20.0
million and recognized a pre-tax gain of $14.9 million.
Income tax expense consists of foreign tax expense and deferred tax
benefit. The deferred tax benefit is due to the loss incurred during the year
ended December 31, 2000.
LIQUIDITY AND CAPITAL RESOURCES
As of December 31, 2001, the Company had cash, cash equivalents and other
short-term investments of $60.4 million, a decrease of $2.9 million from
December 31, 2000. The primary sources of cash in 2001, as reflected on the
consolidated statement of cash flows, were $116.0 million provided by operating
activities and $7.6 million from the disposition of assets. Proceeds from the
disposition of assets included the sale of various non-marketable rigs and
components and reimbursements from customers for equipment lost in the hole.
The primary uses of cash in 2001 were $122.0 million for capital
expenditures and $5.0 million for repayment of debt. Major projects during the
year included modifications to jackup Rig 22 as a result of its scheduled
five-year Coast Guard inspection, completion of Rig 216 to work in the
Karachaganak field in Kazakhstan, and purchase of drill pipe and other rental
tools for Quail. Repayment of debt included $4.5 million on a five-year note
with Boeing Capital Corporation for barge Rig 75 in Nigeria.
As of December 31, 2000, the Company had cash, cash equivalents and other
short-term investments of $63.3 million, an increase of $17.0 million from
December 31, 1999. The primary sources of cash in 2000, as reflected on the
consolidated statement of cash flows, were $87.3 million of net proceeds from a
common stock offering, $31.9 million from the disposition of assets, $27.3
million provided by operating activities and $16.9 million from the sale of
investments. The net proceeds from the equity offering of $87.3 million were the
result of issuing 13.8 million shares of common stock during September 2000.
Proceeds from the disposition of assets included the sale of Rig 245 in Alaska
for $20.0 million, the sale of various non-marketable rigs and components and
reimbursements by our customers for equipment lost in the hole. Also, the
Company sold its 1.0 million shares of Unit Corporation stock in September 2000
for $15.0 million. The Unit stock (and $40.0 million cash) was received in 1999
in conjunction with the sale of the Company's 13 U.S. lower-48 land rigs to Unit
Corporation.
The primary uses of cash in 2000 were $98.5 million for capital
expenditures (net of reimbursements) and $48.3 million for repayment of debt.
Major projects during the year included completion of modifications to Rig 249
for a contract in Kazakhstan for Tengizchevroil (TCO). Additionally, Rig 258 was
constructed for the TCO project and arrived in Kazakhstan during the first
quarter of 2001. During 2000, Rig 259 was purchased and modified for a new
project in the Karachaganak field in Kazakhstan. Also, modifications were
completed on jackup Rig 25 in the Gulf of Mexico as a result of its scheduled
five-year Coast Guard inspection. Repayment of debt included $43.5 million for
the buyback of a portion of the Company's 5.5% Convertible Subordinated Notes,
which resulted in an extraordinary gain of $3.9 million, net of $2.2 million in
taxes, from proceeds from the equity offering and $4.1 million on a five-year
note with Boeing Capital Corporation for barge Rig 75 in Nigeria.
25
LIQUIDITY AND CAPITAL RESOURCES (continued)
The Company has total long-term debt, including the current portion, of
$592.2 million at December 31, 2001, consisting of $452.1 million of 9.75%
Senior Notes, $124.5 million of 5.5% Convertible Subordinated Notes and a
secured promissory note with a balance at December 31, 2001, of $15.6 million.
The Company entered into a $50.0 million revolving credit facility with a group
of banks led by Bank of America on October 22, 1999. This facility is available
for working capital requirements, general corporate purposes and to support
letters of credit. The revolver is collateralized by accounts receivable,
inventory and certain barge rigs located in the Gulf of Mexico. The facility
contains customary affirmative and negative covenants. Availability under the
revolving credit facility is subject to certain borrowing base limitations based
on 80 percent of eligible receivables plus 50 percent of rig materials and
supplies. As of December 31, 2001, the borrowing base was $50.0 million of which
none had been drawn down, but $15.1 million of availability has been used to
support letters of credit that have been issued. Given management's outlook for
2002, it is anticipated that eligible receivables and rig materials and supplies
will be at levels to maintain the borrowing base throughout 2002, and that the
maintenance levels required under the net worth and fixed charge coverage ratio
covenants in the revolver will be exceeded. The revolver terminates on October
22, 2003.
The following tables summarize the Company's future contractual
obligations and other commercial commitments as of December 31, 2001.
After 5
1 Year 2 - 3 Years 4 -5 Years Years Total
------- ----------- ---------- ------- --------
(Dollars in Thousands)
Contractual cash obligations:
Long-term debt (1) $ 5,007 $135,100 $449,980 $ -- $590,087
Operating leases (2) 3,141 5,663 5,000 4,773 18,577
------- -------- -------- ------ --------
Total contractual cash obligations $ 8,148 $140,763 $454,980 $4,773 $608,664
======= ======== ======== ====== ========
Commercial commitments:
Revolving credit facility (3) $ -- $ -- $ -- $ -- $ --
Standby letters of credit (3) 15,184 -- -- -- 15,184
------- -------- -------- ------ --------
Total commercial commitments $15,184 $ -- $ -- $ -- $ 15,184
======= ======== ======== ====== ========
(1) Long-term debt includes the 9.75% Senior Notes, the 5.5% Convertible
Subordinated Notes, and the secured 10.1278% promissory note. For
additional information, see Note 3 in the consolidated financial
statements.
(2) Operating leases consist of lease agreements in excess of one year
for office space, equipment, vehicles and personal property. For
additional information, see Note 10 in the consolidated financial
statements.
(3) The Company has available a $50.0 million revolving credit facility.
As of December 31, 2001, none has been drawn down, but $15.1 million
of availability has been used to support letters of credit that have
been issued. See additional information in the preceding paragraph.
26
LIQUIDITY AND CAPITAL RESOURCES (continued)
The Company does not have any unconsolidated special-purpose entities,
off-balance-sheet financing arrangements or guarantees of third-party financial
obligations. Other than the financial derivative instruments described in Note 4
in the notes to consolidated financial statements, the Company has no energy or
commodity contracts.
The Company anticipates that working capital needs and funds required for
capital spending in 2002 will be met with cash provided by operations. The
Company anticipates cash requirements for capital spending will be approximately
$50 million in 2002. It is management's current intention to hold capital
expenditures at a reduced level relative to 2001 and prior years, and to apply
available free cash flow to repay long-term debt. The amount of debt that can be
repaid is dependent on the results of operations for the Company in 2002. Should
new opportunities requiring additional capital arise, that are not contemplated
in management's current capital expenditure budget, the Company will utilize
cash and short-term investments and, if necessary, its revolving credit
facility. In addition, the Company may seek project financing or equity
participation from outside alliance partners or customers. The Company cannot
predict whether such financing or equity participation would be available on
terms acceptable to the Company.
OTHER MATTERS
Business Risks
Internationally, the Company specializes in drilling geologically
challenging wells in locations that are difficult to access and/or involve harsh
environmental conditions. The Company's international services are primarily
utilized by major and national oil companies in the exploration and development
of reserves of oil. In the United States, the Company primarily drills offshore
in the Gulf of Mexico with barge, jackup and platform rigs for major and
independent oil and gas companies. Business activity is dependent on the
exploration and development activities of the major, independent and national
oil and gas companies that make up the Company's customer base. Generally,
temporary fluctuations in oil and gas prices do not materially affect these
companies' exploration and development activities, and consequently do not
materially affect the operations of the Company, except for the Gulf of Mexico,
where drilling contracts are generally for a shorter term, and oil and gas
companies tend to respond more quickly to upward or downward changes in prices.
Most international contracts are of longer duration and oil and gas companies
have committed to longer term projects to develop reserves and thus short term
fluctuations in price do not tend to affect our operations. However, sustained
increases or decreases in oil and natural gas prices could have an impact on
customers' long-term exploration and development activities, which in turn could
materially affect the Company's operations. Generally, a sustained change in the
price of oil would have a greater impact on the Company's international
operations while a sustained change in the price of natural gas would have a
greater effect on U.S. operations. Due to the locations in which the Company
drills, the Company's operations are subject to interruption, prolonged
suspension and possible expropriation due to political instability and local
community unrest. Further, the Company is exposed to liability issues from
pollution arising out of its operations. The majority of such risks are
transferred to the operator by contract or otherwise insured.
Critical Accounting Policies
The Company considers certain accounting policies related to impairment of
property, plant and equipment, impairment of goodwill and the valuation of
deferred tax assets to be critical policies due to the estimation processes
involved in each. Other significant accounting policies are summarized in Note 1
in the notes to consolidated financial statements.
27
OTHER MATTERS (continued)
Impairment of property, plant and equipment. Management periodically
evaluates the Company's property, plant and equipment to determine that their
net carrying value is not in excess of their net realizable value. These
evaluations are performed when the Company has realized sustained significant
declines in utilization and dayrates and recovery is not contemplated in the
near future. Management considers a number of factors such as estimated future
cash flows, appraisals and current market value analysis in determining net
realizable value. Assets are written down to their fair value if it is below its
net carrying value.
Impairment of goodwill. Management periodically assesses whether the
excess of cost over net assets acquired is impaired based on the ability of the
operation, to which it relates, to generate cash flows in amounts adequate to
recover the carrying value of such assets at the measurement date. If an
impairment is determined, the amount of such impairment is calculated based on
the estimated fair market value of the related assets.
In 2002, Statement of Financial Accounting Standards (SFAS) No. 142,
"Goodwill and Other Intangible Assets," became effective and as a result, the
Company will cease to amortize $189.1 million of goodwill. The Company has
recorded $7.4 million of goodwill amortization in 2001 and would have recorded
$7.4 million of goodwill amortization during 2002. In lieu of amortization, the
Company is required to perform an initial impairment review of goodwill in 2002
and an annual impairment review thereafter. The Company expects to complete the
initial review during the second quarter of 2002.
The Company is currently reviewing its operations to identify appropriate
reporting units, including identification of the related operating assets,
goodwill, and liabilities. Subsequent to the above identification the Company
will estimate the fair value of the reporting unit as a whole, deduct the
estimated fair value of the tangible net assets and compare the residual to the
recorded goodwill attributable to the reporting unit.
Accounting for income taxes. As part of the process of preparing the
consolidated financial statements the Company is required to estimate the income
taxes in each of the jurisdictions in which the Company operates. This process
involves estimating the actual current tax exposure together with assessing
temporary differences resulting from differing treatment of items, such as
depreciation, amortization and certain accrued liabilities for tax and
accounting purposes. These differences and the net operating loss carryforwards
result in deferred tax assets and liabilities, which are included within the
Company's consolidated balance sheet. The Company must then assess the
likelihood that the deferred tax assets will be recovered from future taxable
income and to the extent the Company believes that recovery is not likely, the
Company must establish a valuation allowance. To the extent the Company
establishes a valuation allowance or increases or decreases this allowance in a
period, the Company must include an expense or reduction of expense within the
tax provision in the statement of operations.
Recent Accounting Pronouncements
In June 2001, the Financial Accounting Standards Board (FASB) issued SFAS
No. 141, 142 and 143. SFAS No. 141, "Business Combinations," requires that the
purchase method of accounting be used for all business combinations initiated
after June 30, 2001. SFAS No. 142, "Goodwill and Other Intangible Assets,"
changes the accounting for goodwill from an amortization method to an
impairment-only approach and will be effective January 2002 (see Critical
Accounting Policies above for additional discussion). SFAS No. 143, "Accounting
for Asset Retirement Obligations," requires the capitalization and accrual of
the fair value of a liability for an asset retirement obligation in the period
in which it is incurred, if a reasonable estimate of fair value can be made.
SFAS No. 143 will be effective January 2003. In August 2001, the FASB issued
SFAS No. 144, "Accounting for the Impairment or Disposal of Long-Lived Assets".
SFAS No. 144 supersedes SFAS No. 121 and amends Accounting Principles Board
Opinion No. 30 for the accounting and reporting for discontinued operations as
it relates to long-lived assets. SFAS No. 144 will be effective January 2002.
Other than SFAS No. 142, the Company believes that adoption of these
pronouncements will not have a significant effect on financial position, results
of operations or cash flows.
28
Item 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Interest Rate Risk
In December 2001 the Company began to utilize hedging strategies to manage
fixed-rate interest exposure by entering into one swap agreement. In January
2002, the Company entered into two additional swap agreements. The terms of the
swap agreements are as follows:
Months Notional Amount Fixed Rate Floating Rate
- -------------------------------- --------------- ------------------ ----------------------------
(Dollars in Thousands)
December 2001 - November 2006 $ 50,000 9.75% Three-month LIBOR
plus 446 basis points
January 2002 - November 2006 $ 50,000 9.75% Three-month LIBOR
plus 475 basis points
January 2002 - November 2006 $ 50,000 9.75% Three-month LIBOR
plus 482 basis points
If the floating rate is less than the fixed rate, the counter party will
pay the Company accordingly. If the floating rate exceeds the fixed rate, the
Company will pay the counter party. The fair value of the swap agreement at
December 31, 2001, was not material. The change in the fair value of the swap
agreement will be offset by the change in the fair value of the related debt.
29
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and Stockholders
Parker Drilling Company
In our opinion, the consolidated financial statements listed in the index
appearing under Item 14(a)(1) of the Form 10-K, present fairly, in all material
respects, the financial position of Parker Drilling Company and its subsidiaries
at December 31, 2001 and 2000, and the 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 of
America. In addition, in our opinion, the financial statement schedule listed in
the index appearing under Item 14(a)(2) of the Form 10-K, presents fairly, in
all material respects, the information set forth therein when read in
conjunction with the related consolidated financial statements. These financial
statements and financial statement schedule are the responsibility of the
Company's management; our responsibility is to express an opinion on these
financial statements and financial statement schedule based on our audits. We
conducted our audits of these financial statements in accordance with auditing
standards generally accepted in the United States of America which 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, assessing the accounting principles used and
significant estimates made by management, and evaluating the overall financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
/s/ PricewaterhouseCoopers LLP
PricewaterhouseCoopers LLP
Tulsa, Oklahoma
January 29, 2002
30
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF OPERATIONS
(Dollars in Thousands Except Per Share and Weighted Average Shares Outstanding)
Year Ended December 31,
----------------------------------------------
2001 2000 1999
------------ ------------ ------------
Revenues:
U.S. drilling $ 190,809 $ 148,416 $ 113,989
International drilling 231,527 185,100 182,908
Rental tools 65,629 42,833 27,656
------------ ------------ ------------
Total revenues 487,965 376,349 324,553
------------ ------------ ------------
Operating expenses:
U.S. drilling 112,480 99,197 102,098
International drilling 154,484 132,882 126,226
Rental tools 23,005 15,994 10,910
Depreciation and amortization 97,259 85,060 82,170
General and administration 21,721 20,392 16,312
Reorganization 7,500 -- 3,000
Provision for reduction in carrying
value of certain assets -- 8,300 10,607
------------ ------------ ------------
Total operating expenses 416,449 361,825 351,323
------------ ------------ ------------
Operating income (loss) 71,516 14,524 (26,770)
------------ ------------ ------------
Other income and (expense):
Interest expense (53,015) (57,036) (55,928)
Interest income 3,553 3,691 1,725
Gain on disposition of assets 2,316 17,920 39,070
Other (723) 2,243 1,326
------------ ------------ ------------
Total other income and (expense) (47,869) (33,182) (13,807)
------------ ------------ ------------
Income (loss) before income taxes 23,647 (18,658) (40,577)
Income tax expense (benefit) 12,588 4,323 (2,680)
------------ ------------ ------------
Income (loss) before extraordinary gain 11,059 (22,981) (37,897)
Extraordinary gain on early retirement of debt,
net of deferred tax expense of $2,214 -- 3,936 --
------------ ------------ ------------
Net income (loss) $ 11,059 $ (19,045) $ (37,897)
============ ============ ============
Basic earnings (loss) per share:
Income (loss) before extraordinary gain $ 0.12 $ (0.28) $ (0.49)
Extraordinary gain $ -- $ 0.05 $ --
Net income (loss) $ 0.12 $ (0.23) $ (0.49)
Diluted earnings (loss) per share:
Income (loss) before extraordinary gain $ 0.12 $ (0.28) $ (0.49)
Extraordinary gain $ -- $ 0.05 $ --
Net income (loss) $ 0.12 $ (0.23) $ (0.49)
Number of common shares used in computing
earnings per share:
Basic 92,008,877 81,758,825 77,159,461
Diluted 92,691,033 81,758,825 77,159,461
See accompanying notes to consolidated financial statements.
31
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Dollars in Thousands)
December 31,
------------------------
ASSETS 2001 2000
- ------------------------------------------------------------------- ---------- ----------
Current assets:
Cash and cash equivalents $ 60,400 $ 62,480
Other short-term investments 12 811
Accounts and notes receivable, net of allowance
for bad debts of $2,988 in 2001 and $3,755 in 2000 99,874 123,474
Rig materials and supplies 22,200 16,500
Other current assets 8,966 4,600
---------- ----------
Total current assets 191,452 207,865
---------- ----------
Property, plant and equipment, at cost:
Drilling equipment 1,063,454 940,381
Rental tools 74,085 55,237
Buildings, land and improvements 26,887 22,455
Other 25,606 26,066
Construction in progress 26,142 68,120
---------- ----------
1,216,174 1,112,259
Less accumulated depreciation and amortization 520,645 448,734
---------- ----------
Property, plant and equipment, net 695,529 663,525
---------- ----------
Deferred charges and other assets:
Goodwill, net of accumulated amortization of $35,268
in 2001 and $27,786 in 2000 189,127 196,609
Rig materials and supplies 9,201 12,414
Assets held for disposition 1,800 6,860
Debt issuance costs 8,247 10,311
Other 10,421 9,835
---------- ----------
Total deferred charges and other assets 218,796 236,029
---------- ----------
Total assets $1,105,777 $1,107,419
========== ==========
See accompanying notes to consolidated financial statements.
32
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Continued)
(Dollars in Thousands)
December 31,
---------------------------
LIABILITIES AND STOCKHOLDERS' EQUITY 2001 2000
- ---------------------------------------------------------------- ----------- -----------
Current liabilities:
Current portion of long-term debt $ 5,007 $ 5,043
Accounts payable 33,521 44,445
Accrued liabilities 38,152 32,756
Accrued income taxes 7,054 9,422
----------- -----------
Total current liabilities 83,734 91,666
----------- -----------
Long-term debt (Note 3) 587,165 592,584
Deferred income taxes 16,152 18,467
Other long-term liabilities 6,583 5,539
Commitments and contingencies (Note 10) -- --
Stockholders' equity:
Preferred stock, $1 par value, 1,942,000 shares
authorized, no shares outstanding -- --
Common stock, $0.16 2/3 par value, authorized
140,000,000 shares, issued 92,053,796 shares
(91,723,933 shares in 2000) 15,342 15,287
Capital in excess of par value 432,845 431,043
Accumulated other comprehensive income-net unrealized
gain on investments available for sale (net of taxes of
$227 in 2001 and $190 in 2000) 403 339
Retained earnings (accumulated deficit) (36,447) (47,506)
----------- -----------
Total stockholders' equity 412,143 399,163
----------- -----------
Total liabilities and stockholders' equity $ 1,105,777 $ 1,107,419
=========== ===========
See accompanying notes to consolidated financial statements.
33
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS
(Dollars in Thousands)
Year Ended December 31,
-----------------------------------
2001 2000 1999
--------- -------- --------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) $ 11,059 $(19,045) $(37,897)
Adjustments to reconcile net income (loss) to
net cash provided by operating activities:
Depreciation and amortization 97,259 85,060 82,170
Gain on disposition of assets (2,316) (17,920) (39,070)
Gain on early retirement of debt, net of
deferred tax expense -- (3,936) --
Provision for reduction in carrying value
of certain assets -- 8,300 10,607
Deferred tax expense (benefit) (1,899) (11,302) (13,888)
Other 4,625 5,320 3,503
Change in assets and liabilities:
Accounts and notes receivable 24,158 (47,954) 28,554
Rig materials and supplies (3,807) (1,981) (721)
Other current assets (4,366) 11,150 (3,263)
Accounts payable and accrued liabilities (4,484) 18,356 (21,569)
Accrued income taxes (2,784) 1,098 747
Other assets (1,440) 125 5,312
--------- -------- --------
Net cash provided by operating activities 116,005 27,271 14,485
--------- -------- --------
CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from the sale of assets 7,628 31,912 63,868
Capital expenditures (net of reimbursements) (122,033) (98,525) (49,146)
Proceeds from sale of short-term investments 799 16,925 --
Other, net -- -- (127)
--------- -------- --------
Net cash provided by (used in) investing activities (113,606) (49,688) 14,595
--------- -------- --------
See accompanying notes to consolidated financial statements.
34
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS
(Continued)
(Dollars in Thousands)
Year Ended December 31,
----------------------------------
2001 2000 1999
-------- -------- --------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of debt $ -- $ -- $ 35,186
Proceeds from common stock offering, net -- 87,313 --
Payments for early retirement of debt -- (43,477) --
Principal payments under debt obligations (5,034) (4,854) (43,017)
Other 555 414 (62)
-------- -------- --------
Net cash provided by (used in)
financing activities (4,479) 39,396 (7,893)
-------- -------- --------
Net increase (decrease) in cash and cash equivalents (2,080) 16,979 21,187
Cash and cash equivalents at beginning of year 62,480 45,501 24,314
-------- -------- --------
Cash and cash equivalents at end of year $ 60,400 $ 62,480 $ 45,501
======== ======== ========
Supplemental disclosures of cash flow information:
Cash paid during the year for:
Interest $ 53,257 $ 56,608 $ 56,806
Income taxes $ 14,956 $ 14,527 $ 10,461
Supplemental noncash investing and financing activity:
1.0 million shares of Unit Corporation stock
received on sale of U.S. lower-48 land rigs $ -- $ -- $ 7,562
Net unrealized gain (loss) on investments
available for sale (net of taxes of $37 in 2001,
$717 in 2000 and $908 in 1999) $ 64 $ (1,274) $ 1,613
Note receivable for sale of platform rig $ -- $ -- $ 1,645
See accompanying notes to consolidated financial statements.
35
PARKER DRILLING COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
(Dollars and Shares in Thousands)
Retained Accumulated
Capital in Earnings Other
Common Excess of (Accumulated Comprehensive
Shares Stock Par Value Deficit) Income
------- -------- ---------- ------------ -------------
Balances, December 31, 1998 76,887 $ 12,815 $ 341,699 $ 9,436 $ --
Activity in employees' stock plan 500 83 1,738 -- --
Acquisition of stock from
certain employees (15) (3) (63) -- --
Other comprehensive income-net
unrealized gain on investments
(net of taxes of $908) -- -- -- -- 1,613
Net loss (total comprehensive
loss of $36,284) -- -- -- (37,897) --
------- -------- --------- -------- -------
Balances, December 31, 1999 77,372 12,895 343,374 (28,461) 1,613
Activity in employees' stock plan 552 92 2,656 -- --
Issuance of 13,800,000
common shares 13,800 2,300 85,013 -- --
Other comprehensive income-net
unrealized loss on investments
(net of taxes of $717) -- -- -- -- (1,274)
Net loss (total comprehensive
loss of $20,319) -- -- -- (19,045) --
------- -------- --------- -------- -------
Balances, December 31, 2000 91,724 15,287 431,043 (47,506) 339
Activity in employees' stock plan 330 55 1,802 -- --
Other comprehensive income-net
unrealized gain on investments
(net of taxes of $37) -- -- -- -- 64
Net loss (total comprehensive
loss of $11,123) -- -- -- 11,059 --
------- -------- --------- -------- -------
Balances, December 31, 2001 92,054 $ 15,342 $ 432,845 $(36,447) $ 403
======= ======== ========= ======== =======
See accompanying notes to consolidated financial statements.
36
PARKER DRILLING COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 - Summary of Significant Accounting Policies
Consolidation - The consolidated financial statements include the accounts
of Parker Drilling Company ("Parker Drilling") and all of its majority-owned
subsidiaries (collectively, the "Company").
Operations - The Company provides land and offshore contract drilling
services and rental tools on a worldwide basis to major, independent and
foreign-owned oil and gas companies. At December 31, 2001, the Company's rig
fleet consists of 27 barge drilling and workover rigs, seven offshore jackup
rigs, four offshore platform rigs and 41 land rigs. The Company specializes in
the drilling of deep and difficult wells, drilling in remote and harsh
environments, drilling in transition zones and offshore waters, and in providing
specialized rental tools. The Company also provides a range of services that are
ancillary to its principal drilling services, including engineering, and
logistics, as well as various types of project management.
Drilling Contracts and Rental Revenues - The Company recognizes revenues
and expenses on dayrate contracts as the drilling progresses
(percentage-of-completion method) because the Company does not bear the risk of
completion of the well. For meterage contracts, the Company recognizes the
revenues and expenses upon completion of the well (completed-contract method).
Revenues from rental activities are recognized ratably over the rental term
which is generally less than six months.
Cash and Cash Equivalents - For purposes of the balance sheet and the
statement of cash flows, the Company considers cash equivalents to be all highly
liquid debt instruments that have a remaining maturity of three months or less
at the date of purchase.
Other Short-Term Investments - Other short-term investments include
primarily certificates of deposit, U.S. government securities and commercial
paper having remaining maturities of greater than three months at the date of
purchase and are stated at the lower of cost or market value.
Property, Plant and Equipment - The Company provides for depreciation of
property, plant and equipment primarily on the straight-line method over the
estimated useful lives of the assets after provision for salvage value. The
depreciable lives for land drilling equipment approximate 15 years. The
depreciable lives for offshore drilling equipment generally range from 15 to 20
years. The depreciable lives for certain other equipment, including drill pipe
and rental tools, range from three to seven years. Depreciable lives for
buildings and improvements range from 10 to 30 years. Interest totaling
approximately $1.6 million, $0.5 million and $3.0 million was capitalized during
the years ended December 31, 2001, 2000 and 1999 respectively. When properties
are retired or otherwise disposed of, the related cost and accumulated
depreciation are removed from the accounts and any gain or loss is included in
operations. Management periodically evaluates the Company's assets to determine
that their net carrying value is not in excess of their net realizable value.
Management considers a number of factors such as estimated future cash flows,
appraisals and current market value analysis in determining net realizable
value. Assets are written down to their fair value if it is below its net
carrying value.
37
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 1 - Summary of Significant Accounting Policies (continued)
Goodwill - Goodwill is being amortized on a straight-line basis over 30
years commencing on the dates of the respective acquisitions. The Company
assesses whether the excess of cost over net assets acquired is impaired based
on the ability of the operation, to which it relates, to generate cash flows in
amounts adequate to recover the carrying value of such assets at the measurement
date. If an impairment is determined, the amount of such impairment is
calculated based on the estimated fair market value of the related assets. See
Note 14 regarding recent accounting pronouncements.
Rig Materials and Supplies - Since the Company's international drilling
generally occurs in remote locations, making timely outside delivery of spare
parts uncertain, a complement of parts and supplies is maintained either at the
drilling site or in warehouses close to the operations. During periods of high
rig utilization, these parts are generally consumed and replenished within a
one-year period. During a period of lower rig utilization in a particular
location, the parts, like the related idle rigs, are generally not transferred
to other international locations until new contracts are obtained because of the
significant transportation costs which would result from such transfers. The
Company classifies those parts which are not expected to be utilized in the
following year as long-term assets.
Other Assets - Other assets include the Company's investment in marketable
equity securities. Equity securities that are classified as available for sale
are stated at fair value as determined by quoted market prices. Unrealized
holding gains and losses are excluded from current earnings and are included in
comprehensive income, net of taxes, in a separate component of stockholders'
equity until realized. At December 31, 2001 and 2000, the fair value of equity
securities totaled $1.8 million and $1.7 million, respectively.
In computing realized gains and losses on the sale of equity securities,
the cost of the equity securities sold is determined using the specific cost of
the security when originally purchased.
Other Long-Term Obligations - Included in this account is the accrual of
workers' compensation liability, which is not expected to be paid within the
next year.
Income Taxes - The Company has adopted Statement of Financial Accounting
Standards (SFAS) No. 109, "Accounting for Income Taxes". Under this
pronouncement, deferred tax liabilities and assets are determined based on the
difference between the financial statement and tax basis of assets and
liabilities using enacted tax rates in effect for the year in which the
differences are expected to reverse.
Earnings (Loss) Per Share (EPS) - Basic earnings (loss) per share is
computed by dividing net income (loss), by the weighted average number of common
shares outstanding during the period. The effects of dilutive securities, stock
options and convertible debt are included in the diluted EPS calculation, when
applicable.
Concentrations of Credit Risk - Financial instruments, which potentially
subject the Company to concentrations of credit risk, consist primarily of trade
receivables with a variety of national and international oil and gas companies.
The Company generally does not require collateral on its trade receivables.
38
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 1 - Summary of Significant Accounting Policies (continued)
At December 31, 2001 and 2000, the Company had deposits in domestic banks
in excess of federally insured limits of approximately $57.6 million and $65.9
million, respectively. In addition, the Company had deposits in foreign banks at
December 31, 2001 and 2000 of $3.5 million and $3.3 million, respectively, which
are not federally insured.
The Company's customer base consists of major, integrated, independent and
foreign-owned oil and gas companies. For fiscal year 2001, ChevronTexaco was the
Company's largest customer with approximately 15 percent of total revenues.
Shell Petroleum Development Company of Nigeria was the Company's largest
customer for the years 2000 and 1999, accounting for approximately 10 percent of
total revenues in both years.
Derivative Financial Instruments. The Company adopted Statement of
Financial Accounting Standards No. 133, "Accounting for Derivative Instruments
and Hedging Activities" (SFAS No. 133), as amended by SFAS Nos. 137 and 138.
These statements require that every derivative instrument be recorded on the
balance sheet as either an asset or liability measured by its fair value. These
statements also establish new accounting rules for hedge transactions, which
depend on the nature of the hedge relationship.
The Company uses derivative instruments to hedge exposure to interest rate
risk. For hedges which meet the SFAS No. 133 criteria, the Company formally
designates and documents the instrument as a hedge of a specific underlying
exposure, as well as the risk management objective and strategy for undertaking
each hedge transaction.
Fair Value of Financial Instruments. The carrying amount of the Company's
cash and short-term investments and short-term and long-term debt had fair
values that approximated their carrying amounts, except for the Company's 5.5%
Notes which had a carrying value of $124.5 million and a fair market value of
$110.7 million at December 31, 2001.
Accounting Estimates. The preparation of financial statements in
conformity with generally accepted accounting principles requires management to
make estimates and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenues and expenses
during the reporting period. Actual results could differ from those estimates.
Note 2 - Disposition of Assets
On November 20, 2000, the Company sold its last remaining U.S. land rig,
Rig 245 in Alaska, for $20.0 million. The Company recognized a pre-tax gain of
$14.9 million during the fourth quarter of 2000.
On September 30, 1999, the Company completed the sale of its U.S. lower-48
land rigs to Unit Corporation for $40.0 million cash plus 1.0 million shares of
Unit common stock. The value of such common stock, based on the closing price
for Unit's common stock on September 30, 1999 approximated $7.6 million. The
Company recognized a pre-tax gain of $36.1 million during September 1999. During
September 2000,
39
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 2 - Disposition of Assets (continued)
the Company sold the 1.0 million shares of Unit common stock for $15.0 million.
The Company recognized a pre-tax gain of approximately $7.4 million during the
third quarter of 2000.
During October 1999, the Company sold its Argentina drilling rigs and
inventories (previously classified as assets held for sale) plus one operating
drilling rig, Rig 9 in Bolivia, for total consideration of approximately $9.3
million. The Company recognized a pre-tax gain of approximately $0.8 million
during October 1999 related primarily to the Bolivia rig.
In the third quarter of 1999, it was decided that barge Rig 80, the Gulf
Explorer, would be actively marketed for disposition and therefore was
reclassified to assets held for disposition. The Company reduced the carrying
value by $2.5 million to record the rig at its estimated net realizable value of
$9.0 million. During the fourth quarter of 2000, due to the continued sluggish
drilling market in Southeast Asia, the Company reduced the carrying value of the
Gulf Explorer by an additional $8.3 million. During March 2001, the Company sold
the Gulf Explorer for total consideration of $1.0 million. The Company
recognized a pre-tax gain of approximately $0.5 million.
40
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 3 - Long-term Debt
December 31,
----------------------
2001 2000
--------- ----------
(Dollars in Thousands)
Senior Notes payable in November 2006 with interest
of 9.75% payable semi-annually in May and November,
net of unamortized discount of $1,145 and $1,381
at December 31, 2001 and 2000, respectively
(effective interest rate of 9.88%) $298,855 $298,619
Senior Notes payable in November 2006 with interest
of 9.75% payable semi-annually in May and November,
net of unamortized premium of $3,230 and $3,888
at December 31, 2001 and 2000, respectively
(effective interest rate of 8.97%) 153,210 153,868
Convertible Subordinated Notes payable in July 2004
with interest of 5.5% payable semi-annually in
February and August 124,509 124,509
Secured promissory note to Boeing Capital Corporation
with interest at 10.1278%, principal and interest
payable monthly over a 60-month term 15,589 20,110
Other 9 521
-------- --------
Total debt 592,172 597,627
Less current portion 5,007 5,043
-------- --------
Total long-term debt $587,165 $592,584
======== ========
41
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 3 - Long-Term Debt (continued)
The aggregate maturities of long-term debt for the five years ending
December 31, 2006 are as follows (000's): 2002 - $5,007; 2003 - $5,532; 2004 -
$129,565; 2005 - $0; 2006 - $449,980.
The Senior Notes, which mature in 2006, were initially issued in November
1996 and in March 1998 in amounts of $300 million (Series B) and $150 million
(Series C), respectively. The $300 million issue was sold at a $2.4 million
discount while the $150 million issue was sold at a premium of $5.7 million. In
May 1998, a registration statement was filed by the Company which offered to
exchange the Series B and C Notes for new Series D Notes. The form and terms of
the Series D Notes are identical in all material respects to the form and terms
of the Series B and C Notes, except for certain transfer restrictions and
registration rights relating to the Series C Notes. All of the Series B Notes
except $189 thousand and all of the Series C Notes were exchanged for new Series
D Notes per this offering. The Notes have an interest rate of 9.75 percent and
are guaranteed by substantially all subsidiaries of Parker Drilling, all of
which are wholly owned. The guarantees are joint and several, full, complete and
unconditional. There are currently no restrictions on the ability of the
subsidiaries to transfer funds to Parker Drilling in the form of cash dividends,
loans or advances. Parker Drilling is a holding company with no operations,
other than through its subsidiaries. The non-guarantors are inconsequential,
individually and in the aggregate, to the consolidated financial statements and
separate financial statements of the guarantors are not presented because
management has determined that they would not be material to investors. As
discussed in Note 4, the Company has entered into various interest rate swap
agreements to modify the interest characteristics of the Senior Notes so that
interest associated with the Senior Notes partially becomes variable.
In anticipation of funding the Hercules acquisition, in July 1997, the
Company issued $175 million of Convertible Subordinated Notes due 2004. The
Notes bear interest at 5.5% payable semi-annually in February and August. The
Notes are convertible at the option of the holder into shares of common stock of
Parker Drilling at $15.39 per share at any time prior to maturity. The Notes are
currently redeemable at the option of the Company at certain stipulated prices.
During the fourth quarter of 2000, the Company repurchased on the open market
$50.5 million principal amount of the 5.5% Notes at an average price of 86.11
percent of face value, recognizing an extraordinary gain of $3.9 million, net of
$2.2 million of tax. The Note repurchases were funded with proceeds from an
equity offering in September 2000, whereby the Company sold 13.8 million shares
of common stock for net proceeds of approximately $87.3 million. The amount of
outstanding Notes at the end of 2001 was $124.5 million.
On October 22, 1999, the Company entered into a $50.0 million revolving
loan facility with a group of banks led by Bank of America. The new facility is
available for working capital requirements, general corporate purposes and to
support letters of credit and bears interest at prime plus 0.50% or LIBOR plus
2.50%. At December 31, 2001, no amounts have been drawn down against the
facility but $15.1 million of availability has been used to support letters of
credit that have been issued. The revolver is collateralized by accounts
receivable, inventory and certain barge rigs located in the Gulf of Mexico. The
facility will terminate on October 22, 2003.
On October 7, 1999, a wholly-owned subsidiary of the Company entered into
a loan agreement with Boeing Capital Corporation for the refinancing of a
portion of the capital cost of barge Rig 75. The loan principal of approximately
$24.8 million plus interest is being repaid in 60 monthly payments of
approximately $0.5 million. The loan is collateralized by barge Rig 75 and is
guaranteed by Parker Drilling. The amount of principal outstanding at the end of
2001 was $15.6 million.
42
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 3 - Long-Term Debt (continued)
Each of the 9.75% Senior Notes, 5.5% Convertible Subordinated Notes and
the revolving loan facility contains customary affirmative and negative
covenants, including restrictions on incurrence of debt and sales of assets. The
revolving loan facility contains covenants which require minimum adjusted
tangible net worth, fixed charge coverage ratio and limits annual capital
expenditures. The revolving loan facility prohibits payment of dividends and the
indenture for the 9.75% Senior Notes restricts the payment of dividends.
Note 4 - Derivative Financial Instruments
The Company is exposed to interest rate risk from its fixed-rate debt. The
Company has hedged against the risk of changes in fair value associated with its
$450.0 million 9.75% Senior Notes by entering into a fixed-to-variable interest
rate swap agreement with a notional amount of $50.0 million as of December 31,
2001. Subsequent to December 31, 2001, the Company entered into two additional
fixed-to-variable interest rate swap agreements with a total notional amount of
$100.0 million. The Company assumes no ineffectiveness as each interest rate
swap meets the short-cut method requirements under SFAS No. 133 for fair value
hedges of debt instruments. As a result, changes in the fair value of the
interest rate swaps are offset by changes in the fair value of the debt and no
net gain or loss is recognized in earnings. The estimated fair value of the swap
agreement at December 31, 2001 was not material.
43
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 5 - Income Taxes
Income (loss) before income taxes and extraordinary gain is summarized as
follows (dollars in thousands):
Year Ended December 31,
----------------------------------------
2001 2000 1999
-------- -------- --------
United States $ 8,751 $(29,253) $(47,526)
Foreign 14,896 10,595 6,949
-------- -------- --------
$ 23,647 $(18,658) $(40,577)
======== ======== ========
Income tax expense (benefit) is summarized as follows (dollars in
thousands):
Year Ended December 31,
----------------------------------------
2001 2000 1999
-------- -------- --------
Current:
United States:
Federal $ 530 $ -- $ --
State -- -- 838
Foreign 13,957 15,625 10,370
Deferred:
United States:
Federal (1,846) (10,988) (13,552)
State (53) (314) (336)
-------- -------- --------
$ 12,588 $ 4,323 $ (2,680)
======== ======== ========
44
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 5 - Income Taxes (continued)
Total income tax expense (benefit) differs from the amount computed by
multiplying income (loss) before income taxes by the U.S. federal income tax
statutory rate. The reasons for this difference are as follows (dollars in
thousands):
Year Ended December 31,
----------------------------------------------------------------------
2001 2000 1999
-------------------- -------------------- --------------------
% of % of % of
Pre-Tax Pre-Tax Pre-Tax
Amount Income Amount Income Amount Income
-------- -------- -------- -------- -------- --------
Computed expected tax
expense (benefit) $ 8,276 35% $ (6,530) (35%) $(14,202) (35%)
Foreign taxes, net of
federal benefit 9,072 38% 10,156 54% 6,741 17%
Change in valuation
allowance (9,593) (41%) (6,097) (33%) -- --
Foreign corporation
losses 3,689 16% 4,253 23% 2,438 6%
Goodwill amortization 1,488 6% 1,488 8% 1,488 4%
Other (344) (1%) 1,053 6% 855 1%
-------- -------- -------- -------- -------- --------
Actual tax expense
(benefit) $ 12,588 53% $ 4,323 23% $ (2,680) (7%)
======== ======== ======== ======== ======== ========
45
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 5 - Income Taxes (continued)
The components of the Company's tax assets and (liabilities) as of
December 31, 2001 and 2000 are shown below (dollars in thousands):
December 31,
----------------------
2001 2000
-------- --------
Deferred tax assets:
Net operating loss carryforwards $ 56,025 $ 61,796
Alternative minimum tax carryforwards 983 --
Reserves established against realization
of certain assets 1,874 2,304
Accruals not currently deductible
for tax purposes 6,388 6,476
-------- --------
65,270 70,576
Deferred tax liabilities:
Property, plant and equipment (65,079) (59,090)
Goodwill (6,180) (4,824)
Unrealized gain on investments held
for sale (227) (190)
-------- --------
Net deferred tax (liability) asset (6,216) 6,472
Valuation allowance (9,936) (24,939)
-------- --------
Deferred income tax liability $(16,152) $(18,467)
======== ========
The change in the valuation allowance in 2001 is the result of expired net
operating loss carryforwards and higher utilization of net operating loss
carryforwards previously reserved because they were expected to expire unused.
The Company has a remaining valuation allowance of $9,936,000 with respect to
its deferred tax asset for the amount of net operating loss carryforwards
expected to expire unused for the tax year ending August 31, 2002. However, the
amount of the asset considered realizable could be different in the near term if
estimates of future taxable income change.
At December 31, 2001, the Company had $155,623,000 of net operating loss
carryforwards. For tax purposes the net operating loss carryforwards expire over
a 20-year period ending August 31 as follows: 2002-$27,599,000; 2003-$0;
2004-$5,128,000; 2005-$0; thereafter-$122,896,000.
46
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 - Common Stock and Stockholders' Equity
In September 2000, the Company sold 13.8 million common shares in a public
offering, resulting in net proceeds (after deducting issuance costs) of $87.3
million. The proceeds were used to acquire, upgrade and refurbish certain
offshore and land drilling rigs and for general corporate purposes, including
the repayment of debt (see Note 3).
Stock Plans
The Company's employee and non-employee director stock plans are
summarized as follows:
The 1994 Non-Employee Director Stock Option Plan ("Director Plan")
provides for the issuance of options to purchase up to 200,000 shares of Parker
Drilling's common stock. The option price per share is equal to the fair market
value of a Parker Drilling share on the date of grant. The term of each option
is 10 years, and an option first becomes exercisable six months after the date
of grant. All shares available for issuance under this plan have been granted.
The 1994 Executive Stock Option Plan provides that the directors may grant
a maximum of 2,400,000 shares to key employees of the Company and its
subsidiaries through the granting of stock options, stock appreciation rights
and restricted and deferred stock awards. The option price per share may not be
less than 50 percent of the fair market value of a share on the date the option
is granted, and the maximum term of a non-qualified option may not exceed 15
years and the maximum term of an incentive option is 10 years. All shares
available for issuance under this plan have been granted.
The 1997 Stock Plan is a "broad-based" stock plan, based on the interim
rules of the New York Stock Exchange, that provides that the directors may grant
stock options and restricted stock awards up to a maximum of 4,000,000 shares to
all employees of the Company who, in the opinion of the board of directors, are
in a position to contribute to the growth, management and success of the
Company. More than 50 percent of all awards under this plan have been awarded to
employees who are non-executive officers. The option price per share may not be
less than the fair market value on the date the option is granted for incentive
options and not less than par value of a share of common stock for non-qualified
options. The maximum term of an incentive option is 10 years and the maximum
term of a non-qualified option is 15 years. In July 1999 and April 2001,
2,000,000 and 1,000,000 additional shares, respectively, were registered with
the SEC for granting under the 1997 Stock Plan. As of December 31, 2001, there
were 622,000 shares available for granting.
47
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 - Common Stock and Stockholders' Equity (continued)
Information regarding the Company's stock option plans is summarized
below:
1994 Director Plan
-------------------
Weighted
Average
Exercise
Shares Price
------- --------
Shares under option:
Outstanding at December 31, 1998 190,000 $ 8.702
Granted 10,000 3.281
Exercised -- --
Cancelled -- --
------- --------
Outstanding at December 31, 1999 200,000 8.431
Granted -- --
Exercised -- --
Cancelled -- --
------- --------
Outstanding at December 31, 2000 200,000 8.431
Granted -- --
Exercised -- --
Cancelled -- --
------- --------
Outstanding at December 31, 2001 200,000 $ 8.431
======= ========
48
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 - Common Stock and Stockholders' Equity (continued)
1994 Option Plan
---------------------------------------------
Incentive Options Non-Qualified Options
-------------------- ----------------------
Weighted Weighted
Average Average
Exercise Exercise
Shares Price Shares Price
-------- -------- ---------- --------
Shares under option:
Outstanding at December 31, 1998 622,564 $ 7.227 1,586,936 $ 6.975
Granted -- -- -- --
Exercised -- -- -- --
Cancelled -- -- -- --
-------- -------- ---------- --------
Outstanding at December 31, 1999 622,564 7.227 1,586,936 6.975
Granted -- -- -- --
Exercised -- -- (18,750) 2.250
Cancelled -- -- -- --
-------- -------- ---------- --------
Outstanding at December 31, 2000 622,564 7.227 1,568,186 7.032
Granted -- -- -- --
Exercised (17,000) 4.500 (1,250) 2.250
Cancelled -- -- -- --
-------- -------- ---------- --------
Outstanding at December 31, 2001 605,564 $ 7.303 1,566,936 $ 7.036
======== ======== ========== ========
49
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 - Common Stock and Stockholders' Equity (continued)
1997 Stock Plan
-----------------------------------------------
Incentive Options Non-Qualified Options
---------------------- ----------------------
Weighted Weighted
Average Average
Exercise Exercise
Shares Price Shares Price
---------- -------- ---------- --------
Shares under option:
Outstanding at December 31, 1998 1,873,905 $ 10.750 1,321,595 $ 9.258
Granted 1,003,021 3.189 897,979 3.232
Exercised (1,011) 3.188 (239) 3.188
Cancelled (81,740) 11.410 (153,760) 10.813
---------- -------- ---------- --------
Outstanding at December 31, 1999 2,794,175 8.038 2,065,575 6.523
Granted 50,000 5.938 15,000 5.062
Exercised (92,094) 3.188 (24,370) 3.188
Cancelled (30,130) 8.564 (2,870) 3.188
---------- -------- ---------- --------
Outstanding at December 31, 2000 2,721,951 8.158 2,053,335 6.556
Granted -- -- 1,485,000 5.167
Exercised (137,061) 3.193 (31,915) 3.188
Cancelled -- -- -- --
---------- -------- ---------- --------
Outstanding at December 31, 2001 2,584,890 $ 8.421 3,506,420 $ 6.000
========== ======== ========== ========
50
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 - Common Stock and Stockholders' Equity (continued)
Outstanding Options
-----------------------
Weighted
Average Weighted
Remaining Average
Number of Contractual Exercise
Plan Exercise Prices Shares Life Price
- -------------------------- ------------------ --------- ----------- ---------
1994 Director Plan $ 3.281 - $ 6.125 40,000 4.4 years $ 4.827
$ 8.875 - $ 12.094 160,000 5.5 years $ 9.332
1994 Executive Option Plan
Incentive option $ 4.500 217,554 3.0 years $ 4.500
Incentive option $ 8.875 388,010 5.4 years $ 8.875
Non-qualified $ 2.250 434,946 3.0 years $ 2.250
Non-qualified $ 8.875 1,131,990 5.4 years $ 8.875
1997 Stock Plan
Incentive option $ 3.188 - $ 5.938 810,725 4.4 years $ 3.358
Incentive option $ 8.875 - $ 12.188 1,774,165 5.2 years $ 10.735
Non-qualified $ 2.820 - $ 6.070 2,338,585 5.3 years $ 4.473
Non-qualified $ 8.875 - $ 10.813 1,167,835 5.6 years $ 9.053
Exercisable Options
-----------------------
Weighted
Average
Remaining
Number of Contractual
Plan Exercise Prices Shares Life
- -------------------------- ------------------ --------- -----------
1994 Director Plan $ 3.281 - $ 6.125 40,000 $ 4.827
$ 8.875 - $ 12.094 160,000 $ 9.332
1994 Executive Option Plan
Incentive option $ 4.500 217,554 $ 4.500
Incentive option $ 8.875 388,010 $ 8.875
Non-qualified $ 2.250 434,946 $ 2.250
Non-qualified $ 8.875 1,131,990 $ 8.875
1997 Stock Plan
Incentive option $ 3.188 - $ 5.938 230,747 $ 3.487
Incentive option $ 8.875 - $ 12.188 1,755,669 $ 10.734
Non-qualified $ 2.820 - $ 6.070 914,313 $ 4.086
Non-qualified $ 8.875 - $ 10.813 1,146,331 $ 9.020
51
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 - Common Stock and Stockholders' Equity (continued)
The Company has three additional stock plans which provide for the
issuance of stock for no cash consideration to officers and key non-officer
employees. Under two of the plans, each employee receiving a grant of shares may
dispose of 15 percent of his/her grant on each annual anniversary date from the
date of grant for the first four years and the remaining 40 percent on the fifth
year anniversary. These two plans have a total of 11,375 shares reserved and
available for granting. Shares granted under the third plan are fully vested no
earlier than 24 months from the effective date of the grant and not later than
36 months. The third plan has a total of 1,562,195 shares reserved and available
for granting. No shares were granted under these plans in 2001, 2000 and 1999.
In prior years the Company purchased shares from certain of its employees,
who received stock through its stock purchase plan, at fair market value. At
December 2000, 497,323 shares were held in Treasury. The 604,870 shares held in
Treasury at December 31, 2001 include 98,293 shares purchased by the Company at
the fair market value of $289,479 for the Stock Bonus Plan contribution. The
Plan was funded in January 2002.
The Company has elected the disclosure-only provisions of SFAS No. 123,
"Accounting for Stock-Based Compensation." Accordingly, no compensation cost has
been recognized for the Company's stock option plans when the option price is
equal to or greater than the fair market value of a share of the Company's
common stock on the date of grant. Pro forma net income and earnings per share
are reflected below as if compensation cost had been determined based on the
fair value of the options at their applicable grant date, according to the
provisions of SFAS No. 123.
52
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 - Common Stock and Stockholders' Equity (continued)
Year Ended December 31,
-------------------------------------
2001 2000 1999
---------- ---------- ----------
(Dollars in Thousands)
Income (loss) before extraordinary gain:
As reported $ 11,059 $ (22,981) $ (37,897)
Pro forma $ 7,698 $ (25,941) $ (45,925)
Diluted earnings (loss) per share before extraordinary gain:
As reported $ 0.12 $ (0.28) $ (0.49)
Pro forma $ 0.08 $ (0.32) $ (0.59)
The fair value of each option grant is estimated using the Black-Scholes
option pricing model with the following assumptions:
Expected dividend yield 0.0%
Expected stock volatility 49.0% in 1999
51.6% in 2000
56.3% in 2001
Risk-free interest rate 3.9% - 6.7%
Expected life of options 5 - 7 years
The estimated fair values of options granted during the year ended
December 31, 1999, under the Director Plan was $16,500. Options granted in 2001,
2000 and 1999 under the 1997 Stock Plan had an estimated fair value of
$4,326,000, $203,000 and $3,263,000 respectively.
53
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 - Common Stock and Stockholders' Equity (continued)
Stock Reserved For Issuance
The following is a summary of common stock reserved for issuance:
December 31,
---------------------------
2001 2000
---------- ----------
Stock plans 10,659,380 9,969,570
Stock bonus plan 81,715 106,375
Convertible notes 8,090,254 8,090,254
---------- ----------
Total shares reserved for issuance 18,831,349 18,166,199
========== ==========
Stockholder Rights Plan
The Company adopted a stockholder rights plan on June 25, 1998, to assure
that the Company's stockholders receive fair and equal treatment in the event of
any proposed takeover of the Company and to guard against partial tender offers
and other abusive takeover tactics to gain control of the Company without paying
all stockholders a fair price. The rights plan was not adopted in response to
any specific takeover proposal. Under the rights plan, the Company's board of
directors declared a dividend of one right to purchase one one-thousandth of a
share of a new series of junior participating preferred stock for each
outstanding share of common stock.
The rights may only be exercised 10 days following a public announcement
that a third party has acquired 15 percent or more of the outstanding common
shares of the Company or 10 days following the commencement of, or announcement
of an intention to make a tender offer or exchange offer, the consummation of
which would result in the beneficial ownership by a third party of 15 percent or
more of the common shares. When exercisable, each right will entitle the holder
to purchase one one-thousandth share of the new series of junior participating
preferred stock at an exercise price of $30, subject to adjustment. If a person
or group acquires 15 percent or more of the outstanding common shares of the
Company, each right, in the absence of timely redemption of the rights by the
Company, will entitle the holder, other than the acquiring party, to purchase
for $30, common shares of the Company having a market value of twice that
amount.
The rights, which do not have voting privileges, expire June 30, 2008, and
at the Company's option, may be redeemed by the Company in whole, but not in
part, prior to expiration for $0.01 per right. Until the rights become
exercisable, they have no dilutive effect on earnings per share.
54
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 7 - Reconciliation of Income and Number of Shares Used to Calculate Basic
and Diluted Earnings Per Share (EPS)
For the Twelve Months Ended December 31, 2001
---------------------------------------------
Income Shares Per-Share
(Numerator) (Denominator) Amount
------------ ---------- ---------
Basic EPS:
Net income $ 11,059,000 92,008,877 $ 0.12
Effect of dilutive securities:
Stock options -- 682,156 --
Diluted EPS:
Net income plus assumed conversions $ 11,059,000 92,691,033 $ 0.12
============ ========== =========
For the Twelve Months Ended December 31, 2000
---------------------------------------------
Income (Loss) Shares Per-Share
(Numerator) (Denominator) Amount
------------ ------------- ---------
Basic EPS:
Loss before extraordinary gain $(22,981,000) 81,758,825 $ (0.28)
Extraordinary gain 3,936,000 81,758,825 0.05
Net loss (19,045,000) 81,758,825 (0.23)
Effect of dilutive securities:
Stock options -- -- --
Diluted EPS:
Loss before extraordinary gain (22,981,000) 81,758,825 (0.28)
Extraordinary gain 3,936,000 81,758,825 0.05
Net loss $(19,045,000) 81,758,825 $ (0.23)
============ ========== =========
55
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 7 - Reconciliation of Income and Number of Shares Used to Calculate Basic
and Diluted Earnings Per Share (EPS) (continued)
For the Twelve Months Ended December 31, 1999
---------------------------------------------
Loss Shares Per-Share
(Numerator) (Denominator) Amount
------------ ------------- ---------
Basic EPS:
Net loss $(37,897,000) 77,159,461 $ (0.49)
Effect of dilutive securities:
Stock options -- -- --
Diluted EPS:
Net loss $(37,897,000) 77,159,461 $ (0.49)
============ ========== =========
The Company has outstanding $124,509,000 of 5.5% Convertible Subordinated
Notes, which are convertible into 8,090,254 shares of common stock at $15.39 per
share. The Notes have been outstanding since their issuance in July 1997, but
were not included in the computation of diluted EPS because the assumed
conversion of the Notes would have had an anti-dilutive effect on EPS. For the
fiscal year ended December 31, 2001, options to purchase 6,049,000 shares of
common stock at prices ranging from $5.00 to $12.1875, which were outstanding
during part of the period, were not included in the computation of diluted EPS
because the options' exercise price was greater than the average market price of
the common shares during the period. For the years ended December 31, 2000 and
1999, options to purchase 7,166,036 and 7,269,250 shares of common stock,
respectively, at prices ranging from $2.2500 to $12.1875, were outstanding but
not included in the computation of diluted EPS because the assumed exercise of
the options would have had an anti-dilutive effect on EPS due to the net loss
during those periods.
Note 8 - Employee Benefit Plans
The Parker Drilling Company Stock Bonus Plan ("Plan") was adopted
effective September 1980 for employees of Parker Drilling and its subsidiaries
who are U.S. citizens and who have completed three months of service with the
Company. It was amended in 1983 to qualify as a 401(k) plan under the Internal
Revenue Code which permits a specified percentage of an employee's salary to be
voluntarily contributed on a before-tax basis and to provide for a Company
matching feature. Participants may contribute from one percent to 15 percent of
eligible earnings and direct contributions to one or more of 10 investment
funds. The Plan was amended and restated, effective January 1, 1999, to provide
for dollar-for-dollar matching contributions by the Company up to three percent
of a participant's compensation and $0.50 for every dollar contributed from
three percent to five percent. The Company's matching contribution is made in
Parker Drilling common stock and vests immediately. Each Plan year, additional
Company contributions can be made, at the discretion of the board of directors,
in amounts not exceeding the permissible deductions under the Internal Revenue
Code. The Company issued 343,289, 361,855 and 498,654 shares to the Plan in
2001, 2000 and 1999 with the Company recognizing expense of $1,927,100,
$1,742,193 and $1,492,099 in each of the periods, respectively.
56
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 9 - Business Segments
The Company is organized into three primary business units: U.S. drilling
operations, international drilling operations, and rental tools. This is the
basis management uses for making operating decisions and assessing performance.
Year Ended December 31,
---------------------------------------------
Operations by Industry Segment 2001 2000 1999
- ------------------------------------ ----------- ----------- -----------
(Dollars in Thousands)
Revenues:
U.S. drilling $ 190,809 $ 148,416 $ 113,989
International drilling 231,527 185,100 182,908
Rental tools 65,629 42,833 27,656
----------- ----------- -----------
Total revenues 487,965 376,349 324,553
----------- ----------- -----------
Operating income (loss):
U.S. drilling 33,138 6,766 (31,478)
International drilling 37,583 19,553 26,737
Rental tools 30,016 16,897 7,890
----------- ----------- -----------
Total operating income
by segment (1) 100,737 43,216 3,149
General and administrative (21,721) (20,392) (16,312)
Reorganization (7,500) -- (3,000)
Provision for reduction in
carrying value of certain assets -- (8,300) (10,607)
----------- ----------- -----------
Total operating income (loss) 71,516 14,524 (26,770)
Interest expense (53,015) (57,036) (55,928)
Other income, net 5,146 23,854 42,121
----------- ----------- -----------
Income (loss) before income taxes $ 23,647 $ (18,658) $ (40,577)
=========== =========== ===========
Identifiable assets:
U.S. drilling $ 343,357 $ 356,090 $ 386,385
International drilling 424,022 412,839 357,906
Rental tools 70,365 57,550 43,356
----------- ----------- -----------
Total identifiable assets 837,744 826,479 787,647
Corporate assets 268,033 280,940 295,096
----------- ----------- -----------
Total assets $ 1,105,777 $ 1,107,419 $ 1,082,743
=========== =========== ===========
(1) Operating income by segment is calculated by excluding general and
administrative expense, reorganization expense and provision for
reduction in carrying value of certain assets from operating income,
as reported in the consolidated statements of operations.
57
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 9 - Business Segments (continued)
Year Ended December 31,
---------------------------------------------
Operations by Industry Segment 2001 2000 1999
- ------------------------------------ ----------- ----------- -----------
(Dollars in Thousands)
Capital expenditures:
U.S. drilling $ 41,366 $ 22,221 $ 8,093
International drilling 53,732 55,215 29,937
Rental tools 24,210 16,168 7,221
Corporate 2,725 4,921 3,895
----------- ----------- -----------
Total capital expenditures $ 122,033 $ 98,525 $ 49,146
=========== =========== ===========
Depreciation and amortization:
U.S. drilling $ 44,300 $ 42,458 $ 39,787
International drilling 38,379 30,730 34,046
Rental tools 12,302 11,147 8,261
Corporate 2,278 725 76
----------- ----------- -----------
Total depreciation and amortization $ 97,259 $ 85,060 $ 82,170
=========== =========== ===========
58
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 9 - Business Segments (continued)
Year Ended December 31,
--------------------------------------------
Operations by Geographic Area 2001 2000 1999
- ------------------------------------ ----------- ----------- -----------
(Dollars in Thousands)
Revenues:
United States $ 256,438 $ 191,249 $ 141,645
Latin America 54,063 58,467 85,112
Asia Pacific 32,246 15,373 25,193
Africa and Middle East 58,988 55,671 36,852
Former Soviet Union 86,230 55,589 35,751
----------- ----------- -----------
Total revenues 487,965 376,349 324,553
----------- ----------- -----------
Operating income (loss):
United States 63,154 23,663 (23,587)
Latin America 2,385 6,554 14,661
Asia Pacific 11,304 (1,905) (1,964)
Africa and Middle East 11,933 8,562 8,503
Former Soviet Union 11,961 6,342 5,536
----------- ----------- -----------
Total operating income
by segment (1) 100,737 43,216 3,149
General and administrative (21,721) (20,392) (16,312)
Reorganization (7,500) -- (3,000)
Provision for reduction in
carrying value of certain assets -- (8,300) (10,607)
----------- ----------- -----------
Total operating income (loss) 71,516 14,524 (26,770)
Interest expense (53,015) (57,036) (55,928)
Other income, net 5,146 23,854 42,121
----------- ----------- -----------
Income (loss) before income taxes $ 23,647 $ (18,658) $ (40,577)
=========== =========== ===========
Identifiable assets:
United States $ 681,756 $ 702,639 $ 724,837
Latin America 93,722 93,896 102,348
Asia Pacific 39,963 41,602 60,458
Africa and Middle East 94,986 119,607 105,354
Former Soviet Union 195,350 149,675 89,746
----------- ----------- -----------
Total identifiable assets $ 1,105,777 $ 1,107,419 $ 1,082,743
=========== =========== ===========
(1) Operating income by segment is calculated by excluding general and
administrative expense, reorganization expense and provision for
reduction in carrying value of certain assets from operating income,
as reported in the consolidated statements of operations
59
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 10 - Commitments and Contingencies
At December 31, 2001, the Company had a $50.0 million revolving credit
facility available for general corporate purposes and to support letters of
credit. As of December 31, 2001, $15.1 million of availability has been reserved
to support letters of credit that have been issued. At December 31, 2001, no
amounts had been drawn under the revolving credit facility.
The Company has various lease agreements for office space, equipment,
vehicles and personal property. These obligations extend through 2008 and are
typically non-cancelable. Most leases contain renewal options and certain of the
leases contain escalation clauses. Future minimum lease payments at December 31,
2001, under operating leases with non-cancelable terms in excess of one year,
are as follows:
2002 $ 3,141
2003 2,870
2004 2,793
2005 2,616
2006 2,384
Therafter 4,773
--------
Total $ 18,577
========
Total rent expense for all operating leases amounted to $5.5 million for
2001, $3.7 million for 2000, and $4.0 million for 1999.
Certain officers of the Company entered into Severance Compensation and
Consulting Agreements with the Company (the "Agreements"). A total of nine
officers are currently signatories. The Agreements provide for an initial
six-year term and the payment of certain benefits upon a change of control (as
defined in the Agreements). A change of control includes certain mergers or
reorganizations, changes in the board of directors, sale or liquidation of the
Company or acquisition of more than 15 percent of the outstanding common stock
of the Company by a third party; provided that the board of directors has the
right to preclude triggering of a change of control when a third party acquired
15 percent of the outstanding voting securities if the board of directors
determines within five days that the circumstances of the acquisition did not
warrant implementation of the Agreements. After a change of control occurs, if
an officer is terminated within four years without good cause or resigns within
two years for good reason (as each are defined in the Agreements) the officer
shall receive a payment of three times his annual cash compensation, plus
additional compensation for a one-year consulting agreement at the officer's
annual cash compensation, plus extended life, health and other miscellaneous
benefits for four years.
The drilling of oil and gas wells is subject to various federal, state,
local and foreign laws, rules and regulations. The Company, as an owner or
operator of both onshore and offshore facilities operating in or near waters of
the United States, may be liable for the costs of removal and damages arising
out of a pollution incident to the extent set forth in the Federal Water
Pollution Control Act, as amended by the Oil Pollution Act of 1990 ("OPA") and
the Outer Continental Shelf Lands Act. In addition, the Company may also be
60
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 10 - Commitments and Contingencies (continued)
subject to applicable state law and other civil claims arising out of any such
incident. Certain of the Company's facilities are also subject to regulations of
the Environmental Protection Agency ("EPA") that require the preparation and
implementation of spill prevention, control and countermeasure plans relating to
possible discharge of oil into navigable waters. Other regulations of the EPA
may require certain precautions in storing, handling and transporting hazardous
wastes. State statutory provisions relating to oil and natural gas generally
include requirements as to well spacing, waste prevention, production
limitations, pollution prevention and cleanup, obtaining drilling and dredging
permits and similar matters.
Verdin Lawsuit. Two subsidiaries of Parker Drilling Company
("Subsidiaries") are currently named defendants in the lawsuit, Verdin vs. R & B
Falcon Drilling USA, Inc., et. al., Civil Action No. G-00-488, currently pending
in the U.S. District Court for the Southern District of Texas, Houston Division.
The plaintiff is a former employee of a drilling contractor engaged in offshore
drilling operations in the Gulf of Mexico. The defendants are various drilling
contractors, including the Subsidiaries, who conduct drilling operations in the
Gulf of Mexico. Plaintiff alleges that the defendants have violated federal and
state antitrust laws by agreeing with each other to depress wages and benefits
paid to employees working for said defendants.
Plaintiff sought to bring this case as a "class action", i.e., on behalf
of himself and a proposed class of other similarly situated employees of the
defendants that have allegedly suffered similar damages from the alleged actions
of defendants. Originally, the case was pending in U.S. District Court for the
Southern District of Texas, Galveston Division. Recently, the case was
transferred to the Houston Division. The Subsidiaries and certain of the other
defendants recently entered into a stipulation of settlement with the plaintiff,
pursuant to which the Subsidiaries will pay $625,000 for a full and complete
release of all claims brought in the case. The settlement was preliminarily
approved by the Court on November 8, 2001, and the Court will conduct a fairness
hearing on April 18, 2002, to determine whether the proposed settlement should
receive final approval. The settlement amount and related fees were accrued
during the third quarter 2001.
Kazakhstan Tax Issue. On July 6, 2001, the Ministry of State Revenues of
Kazakhstan ("MSR") issued an Act of Audit to the Kazakhstan branch ("PKD
Kazakhstan") of Parker Drilling Company International Limited, a wholly owned
subsidiary of the Company ("PDCIL"), assessing additional taxes in the amount of
approximately $29,000,000 for the years 1998-2000. The assessment consists
primarily of adjustments in corporate income tax based on a determination by the
Kazakhstan tax authorities that payments by Offshore Kazakhstan International
Operating Company, ("OKIOC"), to PDCIL of $99,050,000, in reimbursement of costs
for modifications to Rig 257, performed by PDCIL prior to the importation of the
drilling rig into Kazakhstan, where it is currently working under contract to
OKIOC, are income to PKD Kazakhstan, and therefore, taxable to PKD Kazakhstan.
PKD Kazakhstan filed an Act of Non-Agreement stating its position that such
payment should not be taxable and requesting the Act of Audit be revised
accordingly. In November, the MSR rejected PKD Kazakhstan's Act of
Non-Agreement, prompting PKD Kazakhstan to seek judicial review of the
assessment. On December 28, 2001, the Astana City Court issued a judgment in
favor of PKD Kazakhstan, finding that the reimbursements to PDCIL were not
income to PKD Kazakhstan and not otherwise subject to tax based on the
U.S.-Kazakhstan Tax Treaty. The MSR has appealed the Astana City Court decision
to the Supreme Court, but has requested and received a postponement in the
hearing until March 21, 2002. Management believes that it is still not possible
to make a reasonable determination as to the probable outcome of this matter.
61
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 10 - Commitments and Contingencies (continued)
The Company is a party to various other lawsuits and claims arising out of
the ordinary course of business. Management, after review and consultation with
legal counsel, considers that any liability resulting from these matters would
not materially affect the results of operations, the financial position or the
net cash flows of the Company.
Note 11 - Related Party Transactions
Since 1975 when the stockholders approved a Stock Purchase Agreement, the
Company and Robert L. Parker have entered into various life insurance
arrangements on the life of Robert L. Parker. To insure the lives of Mr. and
Mrs. Parker for $15.2 million and Mr. Robert L. Parker for $8.0 million the
Company is currently paying $0.6 million in annual premiums. Annual premiums
funded by the Company will be reimbursed from the proceeds of the policies, plus
accrued interest beginning March 2003 at a one-year treasury bill rate. The
Company may use, at its option, up to $7.0 million of such proceeds to purchase
Parker Drilling stock from the Robert L. Parker Sr. Family Limited Partnership
at a discounted price. Robert L. Parker Jr., chief executive officer of the
Company and son of Robert L. Parker, will receive one-third of the net proceeds
of these policies as a beneficiary.
Note 12 - Supplementary Information
At December 31, 2001, accrued liabilities included $8.2 million of accrued
interest expense, $5.3 million of workers' compensation and health plan
liabilities and $10.4 million of accrued payroll and payroll taxes. At December
31, 2000, accrued liabilities included $8.4 million of accrued interest expense,
$6.0 million of workers' compensation and health plan liabilities and $9.9
million of accrued payroll and payroll taxes. Other long-term obligations
included $3.8 million and $3.2 million of workers' compensation liabilities as
of December 31, 2001 and 2000, respectively.
62
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 13 - Selected Quarterly Financial Data (Unaudited)
Quarter
-------------------------------------------------------------------
Year 2001 First Second Third Fourth Total
- ------------------------------- --------- --------- --------- -------- ---------
(Dollars in Thousands Except Per Share Amounts)
Revenues $ 114,874 $ 132,915 $ 128,927 $111,249 $ 487,965
Gross profit (1) $ 22,480 $ 33,333 $ 29,606 $ 15,318 $ 100,737
Operating income $ 17,609 $ 23,130 $ 22,375 $ 8,402 $ 71,516
Net income (3) $ 1,524 $ 2,692 $ 3,025 $ 3,818 $ 11,059
Basic earnings per share: (2)
Net income $ 0.02 $ 0.03 $ 0.03 $ 0.04 $ 0.12
Diluted earnings per share: (2)
Net income $ 0.02 $ 0.03 $ 0.03 $ 0.04 $ 0.12
(1) Gross profit is calculated by excluding general and administrative
expense, reorganization expense and provision for reduction in
carrying value of certain assets from operating income, as reported
in the consolidated statement of operations.
(2) As a result of shares issued during the year, earnings per share for
the year's four quarters, which are based on weighted average shares
outstanding during each quarter, do not equal the annual earnings
per share, which is based on the weighted average shares outstanding
during the year.
(3) The fourth quarter includes a $9.6 million deferred tax benefit
resulting from a reversal of a valuation allowance. See Note 5.
63
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 13 - Selected Quarterly Financial Data (continued) (Unaudited)
Quarter
-------------------------------------------------------------------
Year 2000 First Second Third Fourth Total
- ------------------------------- --------- --------- --------- -------- ---------
(Dollars in Thousands Except Per Share Amounts)
Revenues $ 73,953 $ 86,960 $ 101,849 $113,587 $ 376,349
Gross profit (1) $ (3,931) $ 6,409 $ 15,445 $ 25,293 $ 43,216
Operating income (loss) $ (8,934) $ 1,965 $ 9,953 $ 11,540 $ 14,524
Net income (loss) before
extraordinary gain $ (14,876) $ (9,482) $ (1,034) $ 2,411 $ (22,981)
Extraordinary gain $ -- $ -- $ -- $ 3,936 $ 3,936
Net income (loss) $ (14,876) $ (9,482) $ (1,034) $ 6,347 $ (19,045)
Basic earnings (loss) per
share: (2)
Income (loss) before
extraordinary gain $ (0.19) $ (0.12) $ (0.01) $ 0.03 $ (0.28)
Extraordinary gain $ -- $ -- $ -- $ 0.04 $ 0.05
Net income (loss) $ (0.19) $ (0.12) $ (0.01) $ 0.07 $ (0.23)
Diluted earnings (loss) per
share: (2)
Income (loss) before
extraordinary gain $ (0.19) $ (0.12) $ (0.01) $ 0.03 $ (0.28)
Extraordinary gain $ -- $ -- $ -- $ 0.04 $ 0.05
Net income (loss) $ (0.19) $ (0.12) $ (0.01) $ 0.07 $ (0.23)
(1) Gross profit is calculated by excluding general and administrative
expense, reorganization expense and provision for reduction in
carrying value of certain assets from operating income, as reported
in the Consolidated Statement of Operations.
(2) As a result of shares issued during the year, earnings per share for
the year's four quarters, which are based on weighted average shares
outstanding during each quarter, do not equal the annual earnings
per share, which is based on the weighted average shares outstanding
during the year.
64
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 14 - Recent Accounting Pronouncements
In June 2001, the Financial Accounting Standards Board ("FASB") issued
SFAS No. 141, 142 and 143. SFAS No. 141, "Business Combinations", requires that
the purchase method of accounting be used for all business combinations
initiated after June 30, 2001. SFAS No. 142, "Goodwill and Other Intangible
Assets", changes the accounting for goodwill from an amortization method to an
impairment-only approach and will be effective January 2002. SFAS No. 143,
"Accounting for Asset Retirement Obligations", requires the capitalization and
accrual of the fair value of a liability for an asset retirement obligation in
the period in which it is incurred if a reasonable estimate of fair value can be
made. SFAS No. 143 will be effective January 2003. In August 2001 the FASB
issued SFAS No. 144, "Accounting for the Impairment or Disposal of Long-Lived
Assets". SFAS No. 144 supersedes SFAS No. 121 and amends Accounting Principles
Board Opinion No. 30 for the accounting and reporting for discontinued
operations as it relates to long-lived assets. SFAS No. 144 will be effective
January 2002.
The Company is presently evaluating the effect of these new pronouncements
on its financial position and results of operations and believes that only SFAS
No. 142 will impact the Company because it has recorded a significant amount of
goodwill related to prior acquisitions and recorded annual amortization during
each of the last three years of $7.4 million.
Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
This item is not applicable to the Company in that disclosure is required
under Regulation S-X by the Securities and Exchange Commission only if the
Company had changed independent auditors and, if it had, only under certain
circumstances.
PART III
Item 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information required by this item is shown in Item 14A "Executive
Officers" and hereby incorporated by reference from the information appearing
under the captions "Proposal One - Election of Directors" in the Company's
definitive proxy statement for the Annual Meeting of Stockholders to be held
April 25, 2002, to be filed with the Securities and Exchange Commission
("Commission") within 120 days of the end of the Company's year ended December
31, 2001.
Item 11. EXECUTIVE COMPENSATION
Notwithstanding the foregoing, in accordance with the instructions to Item
402 of Regulations S-K, the information contained in the Company's proxy
statement under the sub-heading "Compensation Committee Report on Executive
Compensation" and "Performance Graph" shall not be deemed to be filed as part of
or incorporated by reference into this Form 10-K.
65
Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The information required by this item is hereby incorporated by reference
from the information appearing under the captions "Principal Stockholders and
Security Ownership of Management" in the Company's definitive proxy statement
for the Annual Meeting of Stockholders to be held April 25, 2002, to be filed
with the Commission within 120 days of the end of the Company's year ended
December 31, 2001.
Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information required by this item is hereby incorporated by reference
to such information appearing under the caption "Other Information" and "Related
Transactions" in the Company's definitive proxy statement for the Annual Meeting
of Stockholders to be held April 25, 2002, to be filed with the Commission
within 120 days of the end of the Company's year ended December 31, 2001.
66
PART IV
Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULE AND REPORTS ON FORM 8-K
(a) The following documents are filed as part of this report:
(1) Financial Statements of Parker Drilling Company and subsidiaries which are
included in Part II, Item 8:
Page
----
Report of Independent Accountants 30
Consolidated Statement of Operations for the years ended
December 31, 2001, 2000 and 1999 31
Consolidated Balance Sheet as of December 31, 2001 and 2000 32
Consolidated Statement of Cash Flows for the years ended
December 31, 2001, 2000 and 1999 34
Consolidated Statement of Stockholders' Equity for the years
ended December 31, 2001, 2000 and 1999 36
Notes to Consolidated Financial Statements 37
67
PART IV
(continued)
Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULE AND REPORTS ON FORM 8-K
(continued)
Page
----
(2) Financial Statement Schedule:
Schedule II - Valuation and qualifying accounts 72
(3) Exhibits:
Exhibit Number Description
- -------------- ------------
3(a) - Corrected Restated Certificate of Incorporation of the
Company, as amended on September 21, 1998 (incorporated by
reference to Exhibit 3(c) to the Company's Annual Report on
Form 10-K for the fiscal year ended August 31, 1998).
3(b) - By-Laws of the Company, as amended July 27, 1999 (incorporated
by reference to Exhibit 3 to the Company's Quarterly Report
on Form 10-Q for the three months ended September 30,
1999).
3(c) - Rights Agreement dated as of July 14, 1998 between the Company
and Norwest Bank Minnesota, N.A., as rights agent
(incorporated by reference to Form 8-A filed July 15, 1998.
68
PART IV (continued)
(3) Exhibits: (continued)
Exhibit Number Description
- -------------- ------------
4(a) - Indenture dated as of March 11, 1998 among the Company, as
issuer, certain Subsidiary Guarantors (as defined therein)
and Chase Bank of Texas, National Association, as Trustee
(incorporated by reference to Exhibit 4.5 to the Company's
S-4 Registration Statement No. 333-49089 dated April 1,
1998).
4(b) - Indenture dated as of July 25, 1997, between the Company and
Chase B Bank of Texas, National Association, f/k/a Texas
Commerce Bank National Association, as Trustee, respecting
5 1/2% Convertible Subordinated Notes due 2004
(incorporated by reference to Exhibit 4.7 to the Company's
S-3 Registration Statement No. 333-30711).
4(c) - Loan and Security Agreement dated as of October 22, 1999,
between the Company and Bank of America, National
Association, as agent for the lenders, regarding the $50.0
million revolving line of credit for loans and letters of
credit due October 22, 2003 (incorporated by reference to
Exhibit 4(c) to the Annual Report on Form 10-K for the year
ended December 31, 2000).
69
PART IV (continued)
Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULE AND REPORTS ON FORM 8-K
(continued)
(3) Exhibits: (continued)
Exhibit Number Description
- -------------- ------------
10(a) - Amended and Restated Parker Drilling Company Stock Bonus Plan,
effective as of January 1, 1999 (incorporated herein by
reference to Exhibit 10(a) to the Company's Quarterly
Report on Form 10-Q for the three months ended March 31,
1999)
10(b) - Form of Severance Compensation and Consulting Agreement
entered into between Parker Drilling Company, and certain
officers of Parker Drilling Company, dated on or about
October 15, 1996 (incorporated herein by reference to
Exhibit 10(g) to Annual Report on Form 10-K for the period
ended August 31, 1996)*
10(c) - 1994 Parker Drilling Company Deferred Compensation Plan
(incorporated herein by reference to Exhibit 10(h) to
Annual Report on Form 10-K for the year ended August 31,
1995).*
10(d) - 1994 Non-Employee Director Stock Option Plan (incorporated
herein by reference to Exhibit 10(i) to Annual Report on
Form 10-K for the year ended August 31, 1995).*
10(e) - 1994 Executive Stock Option Plan (incorporated herein by
reference to Exhibit 10(j) to Annual Report on Form 10-K
for the year ended August 31, 1995).*
10(f) - First Amendment to Severance Compensation and Consulting
Agreement entered into between Parker Drilling Company,
and certain officers of Parker Drilling Company, dated on
or about July 15, 1998.
10(g) - Waiver, Release and Confidentiality Agreement entered into
between James W. Linn and Parker Drilling Company dated
July 17, 2001.
21 - Subsidiaries of the Registrant.
23 - Consent of Independent Accountants.
*Management Contract, Compensatory Plan or Agreement
70
PART IV (continued)
Item 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULE AND REPORTS ON
FORM 8-K (continued)
(b) Reports on Form 8-K: None.
71
PARKER DRILLING COMPANY AND SUBSIDIARIES
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
(Dollars in Thousands)
Column A Column B Column C Column D Column E
- -------------------------------------------------------
Balance Charged
at to cost Balance
beginning and at end of
Classifications of period expenses Deductions period
- -------------------------------------------------------
Year ended December 31, 2001:
Allowance for doubtful accounts
and notes $ 3,755 $ 360 $ 1,127 $ 2,988
Reduction in carrying value of
rig materials and supplies $ 2,491 $ 1,455 $ 1,540 $ 2,406
Deferred tax valuation
allowance $ 24,939 $ (9,593) $ 5,410 $ 9,936
Year ended December 31, 2000:
Allowance for doubtful accounts
and notes $ 5,677 $ 860 $ 2,782 $ 3,755
Reduction in carrying value of
rig materials and supplies $ 1,539 $ 780 $ (172) $ 2,491
Deferred tax valuation
allowance $ 39,109 $ (6,097) $ 8,073 $ 24,939
Year ended December 31, 1999:
Allowance for doubtful accounts
and notes $ 3,002 $ 3,270 $ 595 $ 5,677
Reduction in carrying value of
rig materials and supplies $ 2,572 $ 780 $ 1,813 $ 1,539
Deferred tax valuation
allowance $ 38,469 $ 640 $ -- $ 39,109
72
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized.
PARKER DRILLING COMPANY
By /s/ Robert L. Parker Jr. Date: March 15, 2002
------------------------------
Robert L. Parker Jr.
President and Chief Executive Officer and Director
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
- --------- ----- ----
By: /s/ Robert L. Parker Chairman of the Board March 15, 2002
----------------------------- and Director
Robert L. Parker
By: /s/ Robert L. Parker Jr. President and Chief March 15, 2002
----------------------------- Executive Officer
Robert L. Parker Jr. and Director
(Principal Executive
Officer)
By: /s/ James J. Davis Senior Vice President - March 15, 2002
----------------------------- Finance and Chief
James J. Davis Financial Officer
(Principal Financial
Officer)
By: /s/ Robert F. Nash Senior Vice President March 15, 2002
----------------------------- and Chief Operating
Robert F. Nash Officer
By: /s/ W. Kirk Brassfield Vice President and March 15, 2002
----------------------------- Corporate Controller
W. Kirk Brassfield (Principal Accounting
Officer)
By: /s/ James E. Barnes Director March 15, 2002
-----------------------------
James E. Barnes
By: /s/ Bernard J. Duroc-Danner Director March 15, 2002
-----------------------------
Bernard J. Duroc-Danner
By: /s/ David L. Fist Director March 15, 2002
-----------------------------
David L. Fist
By: /s/ Dr. Robert M. Gates Director March 15, 2002
-----------------------------
Dr. Robert M. Gates
By: /s/ John W. Gibson Director March 15, 2002
-----------------------------
John W. Gibson
By: /s/ Simon G. Kukes Director March 15, 2002
-----------------------------
Simon G. Kukes
By: /s/ James W. Linn Director March 15, 2002
-----------------------------
James W. Linn
By: /s/ R. Rudolph Reinfrank Director March 15, 2002
-----------------------------
R. Rudolph Reinfrank
73
EXHIBIT INDEX
Exhibit Number Description
- -------------- ------------
3(a) - Corrected Restated Certificate of Incorporation of the
Company, as amended on September 21, 1998 (incorporated by
reference to Exhibit 3(c) to the Company's Annual Report on
Form 10-K for the fiscal year ended August 31, 1998).
3(b) - By-Laws of the Company, as amended July 27, 1999 (incorporated
by reference to Exhibit 3 to the Company's Quarterly Report
on Form 10-Q for the three months ended September 30,
1999).
3(c) - Rights Agreement dated as of July 14, 1998 between the Company
and Norwest Bank Minnesota, N.A., as rights agent
(incorporated by reference to Form 8-A filed July 15, 1998.
4(a) - Indenture dated as of March 11, 1998 among the Company, as
issuer, certain Subsidiary Guarantors (as defined therein)
and Chase Bank of Texas, National Association, as Trustee
(incorporated by reference to Exhibit 4.5 to the Company's
S-4 Registration Statement No. 333-49089 dated April 1,
1998).
4(b) - Indenture dated as of July 25, 1997, between the Company and
Chase B Bank of Texas, National Association, f/k/a Texas
Commerce Bank National Association, as Trustee, respecting
5 1/2% Convertible Subordinated Notes due 2004
(incorporated by reference to Exhibit 4.7 to the Company's
S-3 Registration Statement No. 333-30711).
4(c) - Loan and Security Agreement dated as of October 22, 1999,
between the Company and Bank of America, National
Association, as agent for the lenders, regarding the $50.0
million revolving line of credit for loans and letters of
credit due October 22, 2003 (incorporated by reference to
Exhibit 4(c) to the Annual Report on Form 10-K for the year
ended December 31, 2000).
10(a) - Amended and Restated Parker Drilling Company Stock Bonus Plan,
effective as of January 1, 1999 (incorporated herein by
reference to Exhibit 10(a) to the Company's Quarterly
Report on Form 10-Q for the three months ended March 31,
1999)
10(b) - Form of Severance Compensation and Consulting Agreement
entered into between Parker Drilling Company, and certain
officers of Parker Drilling Company, dated on or about
October 15, 1996 (incorporated herein by reference to
Exhibit 10(g) to Annual Report on Form 10-K for the period
ended August 31, 1996)*
10(c) - 1994 Parker Drilling Company Deferred Compensation Plan
(incorporated herein by reference to Exhibit 10(h) to
Annual Report on Form 10-K for the year ended August 31,
1995).*
10(d) - 1994 Non-Employee Director Stock Option Plan (incorporated
herein by reference to Exhibit 10(i) to Annual Report on
Form 10-K for the year ended August 31, 1995).*
10(e) - 1994 Executive Stock Option Plan (incorporated herein by
reference to Exhibit 10(j) to Annual Report on Form 10-K
for the year ended August 31, 1995).*
10(f) - First Amendment to Severance Compensation and Consulting
Agreement entered into between Parker Drilling Company,
and certain officers of Parker Drilling Company, dated on
or about July 15, 1998.
10(g) - Waiver, Release and Confidentiality Agreement entered into
between James W. Linn and Parker Drilling Company dated
July 17, 2001.
21 - Subsidiaries of the Registrant.
23 - Consent of Independent Accountants.
* Management Contract, Compensatory Plan or Agreement