Delaware
|
75-2677995
|
(State
or other jurisdiction of
|
(I.R.S.
Employer
|
incorporation
or organization)
|
Identification
No.)
|
5
Houston Center
|
|
1401
McKinney, Suite 2400
|
|
Houston,
Texas 77010
|
|
(Address
of principal executive offices)
|
|
Telephone
Number - Area code (713) 759-2600
|
|
Securities
registered pursuant to Section 12(b) of the
Act:
|
|
Name
of each Exchange on
|
|
Title
of each class
|
which
registered
|
Common
Stock par value $2.50 per share
|
New
York Stock Exchange
|
Securities
registered pursuant to Section 12(g) of the Act:
None
|
Large
accelerated filer X
|
Accelerated
filer
|
Non-accelerated
filer
|
PART
I
|
PAGE
|
|
Item
1.
|
Business
|
1
|
Item
1(a).
|
Risk
Factors
|
7
|
Item
1(b).
|
Unresolved
Staff Comments
|
7
|
Item
2.
|
Properties
|
8
|
Item
3.
|
Legal
Proceedings
|
9
|
Item
4.
|
Submission
of Matters to a Vote of Security Holders
|
9
|
EXECUTIVE
OFFICERS OF THE REGISTRANT
|
10
|
|
PART
II
|
||
Item
5.
|
Market
for Registrant’s Common Equity, Related Stockholder
Matters
|
|
and
Issuer Purchases of Equity Securities
|
12
|
|
Item
6.
|
Selected
Financial Data
|
12
|
Item
7.
|
Management’s
Discussion and Analysis of Financial Condition and
|
|
Results
of Operations
|
12
|
|
Item
7(a).
|
Quantitative
and Qualitative Disclosures About Market Risk
|
12
|
Item
8.
|
Financial
Statements and Supplementary Data
|
13
|
Item
9.
|
Changes
In and Disagreements with Accountants on Accounting and
|
|
Financial
Disclosure
|
13
|
|
Item
9(a).
|
Controls
and Procedures
|
13
|
Item
9(b).
|
Other
Information
|
13
|
MD&A
AND FINANCIAL STATEMENTS
|
||
Management’s
Discussion and Analysis of Financial Condition and Results of
Operations
|
14
|
|
Management’s
Report on Internal Control Over Financial Reporting
|
61
|
|
Reports
of Independent Registered Public Accounting Firm
|
62
|
|
Consolidated
Statements of Operations
|
64
|
|
Consolidated
Balance Sheets
|
65
|
|
Consolidated
Statements of Shareholders’ Equity
|
66
|
|
Consolidated
Statements of Cash Flows
|
67
|
|
Notes
to Consolidated Financial Statements
|
68
|
|
Selected
Financial Data (Unaudited)
|
114
|
|
Quarterly
Data and Market Price Information (Unaudited)
|
115
|
|
PART
III
|
||
Item
10.
|
Directors
and Executive Officers of the Registrant
|
116
|
Item
11.
|
Executive
Compensation
|
116
|
Item
12(a).
|
Security
Ownership of Certain Beneficial Owners
|
116
|
Item
12(b).
|
Security
Ownership of Management
|
116
|
Item
12(c).
|
Changes
in Control
|
116
|
Item
12(d).
|
Securities
Authorized for Issuance Under Equity Compensation Plans
|
116
|
Item
13.
|
Certain
Relationships and Related Transactions
|
116
|
Item
14.
|
Principal
Accounting Fees and Services
|
116
|
PART
IV
|
||
Item
15.
|
Exhibits
and Financial Statement Schedules
|
117
|
SIGNATURES
|
126
|
-
|
drilling
systems and services;
|
-
|
drill
bits; and
|
-
|
logging
services.
|
-
|
construction,
maintenance, and logistics services for government operations, facilities,
and installations;
|
-
|
civil
engineering, construction, consulting, and project management services
for
state and local government agencies and private
industries;
|
-
|
integrated
security solutions, including threat definition assessments, mitigation,
and consequence management; design, engineering and program management;
construction and delivery; and physical security, operations, and
maintenance;
|
-
|
dockyard
operation and management through the Devonport Royal Dockyard Limited
(DML), which is consolidated for financial reporting purposes, with
services that include design, construction, surface/subsurface fleet
maintenance, nuclear engineering and refueling, and weapons engineering;
and
|
-
|
privately
financed initiatives, in which KBR funds the development or provision
of
an asset, such as a facility, service, or infrastructure for a government
client, which we then own, operate and maintain, enabling our clients
to
utilize new assets at a reasonable
cost.
|
-
|
downstream
engineering and construction capabilities, including global engineering
execution centers, as well as engineering, construction, and program
management of liquefied natural gas (LNG), gas-to-liquids (GTL),
ammonia,
petrochemicals, crude oil refineries, and natural gas
plants;
|
-
|
upstream
deepwater engineering, marine technology, and project
management;
|
-
|
production
services provides plant operations, maintenance, and start-up services
for
upstream oil and gas facilities
worldwide;
|
-
|
in
the United States, industrial services provides maintenance services
to
the petrochemical, forest product, power, and commercial
markets;
|
-
|
industry-leading
licensed technologies in the areas of fertilizers and synthesis gas,
olefins, refining, and chemicals and polymers;
and
|
-
|
consulting
services in the form of expert technical and management advice that
include studies, conceptual and detailed engineering, project management,
construction supervision and design, and construction verification
or
certification in both upstream and downstream
markets.
|
-
|
TSKJ
is a joint venture company formed to design and construct large scale
projects in Nigeria. TSKJ’s members are Technip, SA of France,
Snamprogetti Netherlands B.V., which is an affiliate of ENI SpA of
Italy,
JGC Corporation of Japan, and KBR, each of which owns 25%. TSKJ has
completed five LNG production facilities on Bonny Island, Nigeria
and is
currently working on a sixth such facility. We account for this investment
under the equity method; and
|
-
|
M.
W. Kellogg Limited (MWKL) is a London-based joint venture that provides
full engineering, procurement, and construction contractor services
for
LNG, GTL, and onshore oil and gas projects. MWKL is owned 55% by
KBR and
45% by JGC Corporation. We consolidate MWKL for financial reporting
purposes.
|
-
|
establishing
and maintaining technological
leadership;
|
-
|
achieving
and continuing operational
excellence;
|
-
|
creating
and continuing innovative business relationships;
and
|
-
|
preserving
a dynamic workforce.
|
-
|
price;
|
-
|
service
delivery (including the ability to deliver services and products
on an “as
needed, where needed” basis);
|
-
|
health,
safety, and environmental standards and
practices;
|
-
|
service
quality;
|
-
|
product
quality;
|
-
|
warranty;
and
|
-
|
technical
proficiency.
|
December
31
|
|||||||
Millions
of dollars
|
2005
|
2004
|
|||||
Firm
orders:
|
|||||||
Government
and Infrastructure
|
$
|
3,403
|
$
|
3,968
|
|||
Energy
and Chemicals - Gas monetization
|
3,651
|
443
|
|||||
Energy
and Chemicals - Other
|
2,972
|
3,200
|
|||||
Energy
Services Group segments
|
180
|
64
|
|||||
Total
firm orders
|
10,206
|
7,675
|
|||||
Government
orders firm but not yet funded, letters of
|
|||||||
intent,
and contracts awarded but not signed:
|
|||||||
Government
and Infrastructure
|
1,775
|
816
|
|||||
Total
backlog
|
$
|
11,981
|
$
|
8,491
|
-
|
the
severity and duration of the winter in North America can have a
significant impact on gas storage levels and drilling activity for
natural
gas;
|
-
|
the
timing and duration of the spring thaw in Canada directly affects
activity
levels due to road restrictions;
|
-
|
typhoons
and hurricanes can disrupt coastal and offshore operations;
and
|
-
|
severe
weather during the winter months normally results in reduced activity
levels in the North Sea and Russia.
|
-
|
the
Comprehensive Environmental Response, Compensation and Liability
Act;
|
-
|
the
Resources Conservation and Recovery
Act;
|
-
|
the
Clean Air Act;
|
-
|
the
Federal Water Pollution Control Act;
and
|
-
|
the
Toxic Substances Control Act.
|
Location
|
Owned/Leased
|
Description
|
Energy
Services Group
|
||
Production
Optimization Segment:
|
||
Carrollton,
Texas
|
Owned
|
Manufacturing
facility
|
Alvarado,
Texas
|
Owned/Leased
|
Manufacturing
facility
|
Drilling
and Formation Evaluation Segment:
|
||
The
Woodlands, Texas
|
Leased
|
Manufacturing
facility
|
Shared
Facilities:
|
||
Duncan,
Oklahoma
|
Owned
|
Manufacturing,
technology, and
|
campus
facilities
|
||
Houston,
Texas
|
Owned
|
Manufacturing
and campus facilities
|
Houston,
Texas
|
Owned/Leased
|
Campus
facility
|
Houston,
Texas
|
Leased
|
Campus
facility
|
KBR
|
||
Government
and Infrastructure Segment:
|
||
Arlington,
Virginia
|
Leased
|
Campus
facility
|
Energy
and Chemicals Segment:
|
||
Houston,
Texas
|
Leased
|
Campus
facility
|
Shared
Facilities:
|
||
Houston,
Texas
|
Owned
|
Campus
facility
|
Leatherhead,
United Kingdom
|
Owned
|
Campus
facility
|
Corporate
|
||
Houston,
Texas
|
Leased
|
Corporate
executive offices
|
Name
and Age
|
Offices
Held and Term of Office
|
* Albert
O. Cornelison, Jr.
|
Executive
Vice President and General Counsel of Halliburton
Company,
|
(Age 56)
|
since
December 2002
|
Vice
President and General Counsel of Halliburton Company, May 2002
to
|
|
December
2002
|
|
Vice
President and Associate General Counsel of Halliburton
Company,
|
|
October
1998 to May 2002
|
|
* C.
Christopher Gaut
|
Executive
Vice President and Chief Financial Officer of Halliburton
Company,
|
(Age 49)
|
since
March 2003
|
Senior
Vice President, Chief Financial Officer and Member - Office of
the
|
|
President
and Chief Operating Officer of ENSCO International,
Inc.,
|
|
January
2002 to February 2003
|
|
Senior
Vice President and Chief Financial Officer of ENSCO
International,
|
|
Inc.,
December 1987 to December 2001
|
|
* Andrew
R. Lane
|
Executive
Vice President and Chief Operating Officer of Halliburton
Company,
|
(Age 46)
|
since
December 2004
|
President
and Chief Executive Officer of Kellogg Brown & Root, Inc., July 2004
to
|
|
November
2004
|
|
Senior
Vice President, Global Operations of Halliburton Energy Services
Group,
|
|
April
2004 to July 2004
|
|
President,
Landmark Division of Halliburton Energy Services Group,
|
|
May
2003 to March 2004
|
|
President
and Chief Executive Officer of Landmark Graphics, April 2002
to
|
|
April
2003
|
|
Chief
Operating Officer of Landmark Graphics, January 2002 to March
2002
|
|
Vice
President, Production Enhancement PSL, Completion Products PSL
and
|
|
Tools/Testing/TCP
of Halliburton Energy Services Group, January 2000
|
|
to
December 2001
|
|
* David
J. Lesar
|
Chairman
of the Board, President and Chief Executive Officer of
Halliburton
|
(Age 52)
|
Company,
since August 2000
|
Director
of Halliburton Company, since August 2000
|
|
President
and Chief Operating Officer of Halliburton Company, May 1997
to
|
|
August
2000
|
|
Chairman
of the Board of Kellogg Brown & Root, Inc., January 1999
to
|
|
August
2000
|
|
Executive
Vice President and Chief Financial Officer of Halliburton
Company,
|
|
August
1995 to May 1997
|
|
Mark A. McCollum
|
Senior
Vice President and Chief Accounting Officer of Halliburton
Company,
|
(Age 46)
|
since
August 2003
|
Senior
Vice President and Chief Financial Officer of Tenneco Automotive,
Inc.,
|
|
November
1999 to August 2003
|
Name
and Age
|
Offices
Held and Term of Office
|
Craig W. Nunez
|
Vice
President and Treasurer of Halliburton Company, since February
2006
|
(Age 44)
|
Treasurer
of Colonial Pipeline Company, November 1999 to January
2006
|
* Lawrence
J. Pope
|
Vice
President, Human Resources & Administration of Halliburton
Company,
|
(Age 38)
|
since
January 2006
|
Senior
Vice President, Administration of Kellogg Brown & Root,
Inc.,
|
|
August
2004 to January 2006
|
|
Director,
Finance and Administration for Drilling and Formation
Evaluation
|
|
Division
of Halliburton Energy Services Group, July 2003 to August
2004
|
|
Division
Vice President, Human Resources for Halliburton Energy Services
Group,
|
|
May
2001 to July 2003
|
|
Director,
Human Resources for Halliburton Energy Services Group,
|
|
May
1999 to May 2001
|
|
David R. Smith
|
Vice
President, Tax of Halliburton Company, since May 2002
|
(Age 59)
|
Vice
President, Tax of Halliburton Energy Services, Inc.,
|
September
1998 to May 2002
|
Total
Number of Shares
|
||||||||||
Purchased
as Part of Publicly
|
||||||||||
Period
|
Total
Number of
Shares
Purchased
(a)
|
Average
Price
Paid
per
Share
|
Announced
Plans or Programs
|
|||||||
October
1-31
|
14,775
|
$
|
66.57
|
-
|
||||||
November
1-30
|
3,551
|
$
|
60.32
|
-
|
||||||
December
1-31
|
19,162
|
$
|
64.16
|
-
|
||||||
Total
|
37,488
|
$
|
64.75
|
-
|
Page
No.
|
|
Management’s
Report on Internal Control Over Financial Reporting
|
61
|
Reports
of Independent Registered Public Accounting Firm
|
62
|
Consolidated
Statements of Operations for the years ended December 31, 2005, 2004,
and
2003
|
64
|
Consolidated
Balance Sheets at December 31, 2005 and 2004
|
65
|
Consolidated
Statements of Shareholders’ Equity for the years ended
|
|
December
31, 2005, 2004, and 2003
|
66
|
Consolidated
Statements of Cash Flows for the years ended December 31, 2005, 2004,
and
2003
|
67
|
Notes
to Consolidated Financial Statements
|
68
|
Selected
Financial Data (Unaudited)
|
114
|
Quarterly
Data and Market Price Information (Unaudited)
|
115
|
-
|
higher
demand for oilfield services, with annual average worldwide rig counts
increasing approximately 15%;
|
-
|
improved
utilization of equipment, which was evident by an increase in our
revenue
per fracturing job over 2004;
|
-
|
increased
pricing, particularly in areas of high demand and tight supply;
and
|
-
|
our
continued focus on operating performance and return on capital. Our
focus
centered on exiting underperforming operations, achieving improved
contract terms with our customers, and redeploying resources to more
attractive markets.
|
-
|
large
losses in 2004 on our offshore fixed-price engineering, procurement,
installation, and commissioning (EPIC) projects that did not recur
in
2005, combined with improved profitability on our cost-reimbursable
engineering projects;
|
-
|
award
fees received for our work in Iraq and the complete resolution of
disputed
dining facilities, fuel costs, and other issues, which resulted in
the
recording of $103 million of operating income related to our LogCAP
and
RIO contracts; and
|
-
|
profit
on newly awarded liquefied natural gas (LNG) and gas-to-liquids (GTL),
or
gas monetization infrastructure projects, designed to commercialize
gas
reserves around the world. Our backlog in these gas monetization
projects
was $3.7 billion at December 31,
2005.
|
-
|
improving
the utilization of our equipment and deploying additional resources
to
address the growing demand for our services and
products;
|
-
|
increasing
pricing (as the market allows) for ESG’s services and products due to
expected labor and material cost increases and high demand from
customers;
|
-
|
leveraging
our technologies to provide our customers with the ability to more
efficiently drill wells and to increase the productivity of those
wells;
|
-
|
capitalizing
on our strengths in the LNG and GTL markets. Forecasted LNG market
growth
remains strong and is expected to grow further. Significant numbers
of new
LNG liquefaction plant and LNG receiving terminal projects are proposed
worldwide and are in various stages of development. Our experience
in
providing engineering, design, and construction services in the liquefied
natural gas industry, particularly liquefaction facilities, positions
us
to benefit from the growth we are seeing in this industry;
and
|
-
|
diversifying
the services of our Government and Infrastructure segment. We expect
our
work under the LogCAP contract to see a more rapid decline during
2006
than we saw in 2005. As a result, we are focused on diversifying
the
Government and Infrastructure project portfolio and we continued
to expand
our work for the United States Navy under the CONCAP construction
contingency contract and are positioned for future contingency work
for
the United States Air Force under the AFCAP contract. In addition,
we have
strengthened our position with the United Kingdom Ministry of
Defence.
|
Millions
of dollars
|
||||
2006
|
$
|
193
|
||
2007
|
41
|
|||
2008
|
46
|
|||
2009
|
131
|
|||
2010
|
16
|
|||
Total
|
$
|
427
|
Millions
of dollars
|
||||
Cash
payments related to asbestos and silica made in
2005:
|
||||
Payment
to the asbestos and silica trust in accordance with
|
||||
the
plan of reorganization
|
$
|
2,345
|
||
One-year
non-interest-bearing note for the benefit of
|
||||
asbestos
claimants
|
31
|
|||
Cash
payment related to insurance partitioning agreement
|
||||
in
October 2004 - first of three installments
|
16
|
|||
First
installment payment for the silica note
|
15
|
|||
Payments
related to RHI Refractories agreement
|
11
|
|||
Total
|
$
|
2,418
|
Payments
due
|
||||||||||||||||||||||
Millions
of dollars
|
2006
|
2007
|
2008
|
2009
|
2010
|
Thereafter
|
Total
|
|||||||||||||||
Long-term
debt (1) (2)
|
$
|
359
|
$
|
31
|
$
|
152
|
$
|
1
|
$
|
750
|
$
|
1,879
|
$
|
3,172
|
||||||||
Operating
leases
|
187
|
148
|
123
|
111
|
100
|
478
|
1,147
|
|||||||||||||||
Purchase
obligations (3)
|
644
|
30
|
19
|
10
|
4
|
10
|
717
|
|||||||||||||||
Barracuda-Caratinga
|
12
|
-
|
-
|
-
|
-
|
-
|
12
|
|||||||||||||||
Pension
funding
|
||||||||||||||||||||||
obligations
(4)
|
164
|
-
|
-
|
-
|
-
|
-
|
164
|
|||||||||||||||
Total
|
$
|
1,366
|
$
|
209
|
$
|
294
|
$
|
122
|
$
|
854
|
$
|
2,367
|
$
|
5,212
|
-
|
spending
on upstream exploration, development, and production programs by
major,
national, and independent oil and gas
companies;
|
-
|
capital
expenditures for downstream refining, processing, petrochemical,
gas
monetization, and marketing facilities by major, national, and independent
oil and gas companies; and
|
-
|
government
spending levels.
|
Average
Oil Prices (dollars
per barrel)
|
2005
|
2004
|
2003
|
|||||||
West
Texas Intermediate
|
$
|
56.30
|
$
|
41.31
|
$
|
31.14
|
||||
United
Kingdom Brent
|
$
|
54.45
|
$
|
38.14
|
$
|
28.78
|
||||
Average
United States Gas Prices (dollars
per million cubic feet)
|
||||||||||
Henry
Hub
|
$
|
8.79
|
$
|
5.85
|
$
|
5.63
|
Land
vs. Offshore
|
2005
|
2004
|
2003
|
|||||||
United
States:
|
||||||||||
Land
|
1,287
|
1,093
|
924
|
|||||||
Offshore
|
93
|
97
|
108
|
|||||||
Total
|
1,380
|
1,190
|
1,032
|
|||||||
Canada:
|
||||||||||
Land
|
454
|
365
|
368
|
|||||||
Offshore
|
4
|
4
|
4
|
|||||||
Total
|
458
|
369
|
372
|
|||||||
International
(excluding Canada):
|
||||||||||
Land
|
643
|
594
|
544
|
|||||||
Offshore
|
265
|
242
|
226
|
|||||||
Total
|
908
|
836
|
770
|
|||||||
Worldwide
total
|
2,746
|
2,395
|
2,174
|
|||||||
Land
total
|
2,384
|
2,052
|
1,836
|
|||||||
Offshore
total
|
362
|
343
|
338
|
|||||||
Oil
vs. Gas
|
2005
|
2004
|
2003
|
|||||||
United
States:
|
||||||||||
Oil
|
194
|
165
|
157
|
|||||||
Gas
|
1,186
|
1,025
|
875
|
|||||||
Total
|
1,380
|
1,190
|
1,032
|
|||||||
* Canada:
|
458
|
369
|
372
|
|||||||
International
(excluding Canada):
|
||||||||||
Oil
|
703
|
648
|
576
|
|||||||
Gas
|
205
|
188
|
194
|
|||||||
Total
|
908
|
836
|
770
|
|||||||
Worldwide
total
|
2,746
|
2,395
|
2,174
|
-
|
growth
in worldwide petroleum demand remains robust, despite high oil
prices;
|
-
|
projected
growth in non-Organization of Petroleum Exporting Countries (non-OPEC)
supplies is not expected to accommodate worldwide demand
growth;
|
-
|
worldwide
spare crude oil production capacity has recently diminished and is
projected to remain low;
|
-
|
downstream
sectors, such as refining and shipping, are expected to keep the
level of
uncertainty in world oil markets high as there is limited refining
capacity available, particularly in the United States;
and
|
-
|
loss
of additional capacity due to recent hurricanes in an already tight
refining market.
|
REVENUE:
|
Increase
|
Percentage
|
|||||||||||
Millions
of dollars
|
2005
|
2004
|
(Decrease)
|
Change
|
|||||||||
Production
Optimization
|
$
|
4,284
|
$
|
3,303
|
$
|
981
|
30
|
%
|
|||||
Fluid
Systems
|
2,838
|
2,324
|
514
|
22
|
|||||||||
Drilling
and Formation Evaluation
|
2,258
|
1,782
|
476
|
27
|
|||||||||
Digital
and Consulting Solutions
|
720
|
589
|
131
|
22
|
|||||||||
Total
Energy Services Group
|
10,100
|
7,998
|
2,102
|
26
|
|||||||||
Government
and Infrastructure
|
8,148
|
9,393
|
(1,245
|
)
|
(13
|
)
|
|||||||
Energy
and Chemicals
|
2,746
|
3,075
|
(329
|
)
|
(11
|
)
|
|||||||
Total
KBR
|
10,894
|
12,468
|
(1,574
|
)
|
(13
|
)
|
|||||||
Total
revenue
|
$
|
20,994
|
$
|
20,466
|
$
|
528
|
3
|
%
|
|||||
Geographic
- Energy Services Group segments only:
|
|||||||||||||
Production
Optimization:
|
|||||||||||||
North
America
|
$
|
2,380
|
$
|
1,694
|
$
|
686
|
40
|
%
|
|||||
Latin
America
|
384
|
335
|
49
|
15
|
|||||||||
Europe/Africa/CIS
|
924
|
802
|
122
|
15
|
|||||||||
Middle
East/Asia
|
596
|
472
|
124
|
26
|
|||||||||
Subtotal
|
4,284
|
3,303
|
981
|
30
|
|||||||||
Fluid
Systems:
|
|||||||||||||
North
America
|
1,424
|
1,104
|
320
|
29
|
|||||||||
Latin
America
|
374
|
338
|
36
|
11
|
|||||||||
Europe/Africa/CIS
|
659
|
568
|
91
|
16
|
|||||||||
Middle
East/Asia
|
381
|
314
|
67
|
21
|
|||||||||
Subtotal
|
2,838
|
2,324
|
514
|
22
|
|||||||||
Drilling
and Formation Evaluation:
|
|||||||||||||
North
America
|
805
|
610
|
195
|
32
|
|||||||||
Latin
America
|
365
|
281
|
84
|
30
|
|||||||||
Europe/Africa/CIS
|
497
|
412
|
85
|
21
|
|||||||||
Middle
East/Asia
|
591
|
479
|
112
|
23
|
|||||||||
Subtotal
|
2,258
|
1,782
|
476
|
27
|
|||||||||
Digital
and Consulting Solutions:
|
|||||||||||||
North
America
|
210
|
201
|
9
|
4
|
|||||||||
Latin
America
|
221
|
128
|
93
|
73
|
|||||||||
Europe/Africa/CIS
|
168
|
142
|
26
|
18
|
|||||||||
Middle
East/Asia
|
121
|
118
|
3
|
3
|
|||||||||
Subtotal
|
720
|
589
|
131
|
22
|
|||||||||
Total
Energy Services Group revenue
|
|||||||||||||
by
region:
|
|||||||||||||
North
America
|
4,819
|
3,609
|
1,210
|
34
|
|||||||||
Latin
America
|
1,344
|
1,082
|
262
|
24
|
|||||||||
Europe/Africa/CIS
|
2,248
|
1,924
|
324
|
17
|
|||||||||
Middle
East/Asia
|
1,689
|
1,383
|
306
|
22
|
|||||||||
Total
Energy Services Group revenue
|
$
|
10,100
|
$
|
7,998
|
$
|
2,102
|
26
|
%
|
OPERATING
INCOME (LOSS):
|
Increase
|
Percentage
|
|||||||||||
Millions
of dollars
|
2005
|
2004
|
(Decrease)
|
Change
|
|||||||||
Production
Optimization
|
$
|
1,106
|
$
|
633
|
$
|
473
|
75
|
%
|
|||||
Fluid
Systems
|
544
|
348
|
196
|
56
|
|||||||||
Drilling
and Formation Evaluation
|
483
|
225
|
258
|
115
|
|||||||||
Digital
and Consulting Solutions
|
146
|
60
|
86
|
143
|
|||||||||
Total
Energy Services Group
|
2,279
|
1,266
|
1,013
|
80
|
|||||||||
Government
and Infrastructure
|
330
|
84
|
246
|
293
|
|||||||||
Energy
and Chemicals
|
168
|
(426
|
)
|
594
|
NM
|
||||||||
Total
KBR
|
498
|
(342
|
)
|
840
|
NM
|
||||||||
General
corporate
|
(115
|
)
|
(87
|
)
|
(28
|
)
|
(32
|
)
|
|||||
Total
operating
income
|
$
|
2,662
|
$
|
837
|
$
|
1,825
|
218
|
%
|
|||||
Geographic
- Energy Services Group segments only:
|
|||||||||||||
Production
Optimization:
|
|||||||||||||
North
America
|
$
|
765
|
$
|
376
|
$
|
389
|
103
|
%
|
|||||
Latin
America
|
63
|
56
|
7
|
13
|
|||||||||
Europe/Africa/CIS
|
150
|
110
|
40
|
36
|
|||||||||
Middle
East/Asia
|
128
|
91
|
37
|
41
|
|||||||||
Subtotal
|
1,106
|
633
|
473
|
75
|
|||||||||
Fluid
Systems:
|
|||||||||||||
North
America
|
332
|
186
|
146
|
78
|
|||||||||
Latin
America
|
58
|
55
|
3
|
5
|
|||||||||
Europe/Africa/CIS
|
103
|
70
|
33
|
47
|
|||||||||
Middle
East/Asia
|
51
|
37
|
14
|
38
|
|||||||||
Subtotal
|
544
|
348
|
196
|
56
|
|||||||||
Drilling
and Formation Evaluation:
|
|||||||||||||
North
America
|
217
|
102
|
115
|
113
|
|||||||||
Latin
America
|
54
|
24
|
30
|
125
|
|||||||||
Europe/Africa/CIS
|
88
|
39
|
49
|
126
|
|||||||||
Middle
East/Asia
|
124
|
60
|
64
|
107
|
|||||||||
Subtotal
|
483
|
225
|
258
|
115
|
|||||||||
Digital
and Consulting Solutions:
|
|||||||||||||
North
America
|
62
|
58
|
4
|
7
|
|||||||||
Latin
America
|
17
|
(5
|
)
|
22
|
NM
|
||||||||
Europe/Africa/CIS
|
46
|
(5
|
)
|
51
|
NM
|
||||||||
Middle
East/Asia
|
21
|
12
|
9
|
75
|
|||||||||
Subtotal
|
146
|
60
|
86
|
143
|
|||||||||
Total
Energy Services Group
|
|||||||||||||
operating
income by region:
|
|||||||||||||
North
America
|
1,376
|
722
|
654
|
91
|
|||||||||
Latin
America
|
192
|
130
|
62
|
48
|
|||||||||
Europe/Africa/CIS
|
387
|
214
|
173
|
81
|
|||||||||
Middle
East/Asia
|
324
|
200
|
124
|
62
|
|||||||||
Total
Energy Services Group
|
|||||||||||||
operating
income
|
$
|
2,279
|
$
|
1,266
|
$
|
1,013
|
80
|
%
|
REVENUE:
|
Increase
|
Percentage
|
|||||||||||
Millions
of dollars
|
2004
|
2003
|
(Decrease)
|
Change
|
|||||||||
Production
Optimization
|
$
|
3,303
|
$
|
2,758
|
$
|
545
|
20
|
%
|
|||||
Fluid
Systems
|
2,324
|
2,039
|
285
|
14
|
|||||||||
Drilling
and Formation Evaluation
|
1,782
|
1,643
|
139
|
8
|
|||||||||
Digital
and Consulting Solutions
|
589
|
555
|
34
|
6
|
|||||||||
Total
Energy Services Group
|
7,998
|
6,995
|
1,003
|
14
|
|||||||||
Government
and Infrastructure
|
9,393
|
5,417
|
3,976
|
73
|
|||||||||
Energy
and Chemicals
|
3,075
|
3,859
|
(784
|
)
|
(20
|
)
|
|||||||
Total
KBR
|
12,468
|
9,276
|
3,192
|
34
|
|||||||||
Total
revenue
|
$
|
20,466
|
$
|
16,271
|
$
|
4,195
|
26
|
%
|
|||||
Geographic
- Energy Services Group segments only:
|
|||||||||||||
Production
Optimization:
|
|||||||||||||
North
America
|
$
|
1,694
|
$
|
1,337
|
$
|
357
|
27
|
%
|
|||||
Latin
America
|
335
|
317
|
18
|
6
|
|||||||||
Europe/Africa/CIS
|
802
|
643
|
159
|
25
|
|||||||||
Middle
East/Asia
|
472
|
461
|
11
|
2
|
|||||||||
Subtotal
|
3,303
|
2,758
|
545
|
20
|
|||||||||
Fluid
Systems:
|
|||||||||||||
North
America
|
1,104
|
990
|
114
|
12
|
|||||||||
Latin
America
|
338
|
258
|
80
|
31
|
|||||||||
Europe/Africa/CIS
|
568
|
516
|
52
|
10
|
|||||||||
Middle
East/Asia
|
314
|
275
|
39
|
14
|
|||||||||
Subtotal
|
2,324
|
2,039
|
285
|
14
|
|||||||||
Drilling
and Formation Evaluation:
|
|||||||||||||
North
America
|
610
|
558
|
52
|
9
|
|||||||||
Latin
America
|
281
|
261
|
20
|
8
|
|||||||||
Europe/Africa/CIS
|
412
|
386
|
26
|
7
|
|||||||||
Middle
East/Asia
|
479
|
438
|
41
|
9
|
|||||||||
Subtotal
|
1,782
|
1,643
|
139
|
8
|
|||||||||
Digital
and Consulting Solutions:
|
|||||||||||||
North
America
|
201
|
200
|
1
|
1
|
|||||||||
Latin
America
|
128
|
71
|
57
|
80
|
|||||||||
Europe/Africa/CIS
|
142
|
143
|
(1
|
)
|
(1
|
)
|
|||||||
Middle
East/Asia
|
118
|
141
|
(23
|
)
|
(16
|
)
|
|||||||
Subtotal
|
589
|
555
|
34
|
6
|
|||||||||
Total
Energy Services Group
|
|||||||||||||
revenue
by region:
|
|||||||||||||
North
America
|
3,609
|
3,085
|
524
|
17
|
|||||||||
Latin
America
|
1,082
|
907
|
175
|
19
|
|||||||||
Europe/Africa/CIS
|
1,924
|
1,688
|
236
|
14
|
|||||||||
Middle
East/Asia
|
1,383
|
1,315
|
68
|
5
|
|||||||||
Total
Energy Services Group
|
|||||||||||||
revenue
|
$
|
7,998
|
$
|
6,995
|
$
|
1,003
|
14
|
%
|
OPERATING
INCOME (LOSS):
|
Increase
|
Percentage
|
|||||||||||
Millions
of dollars
|
2004
|
2003
|
(Decrease)
|
Change
|
|||||||||
Production
Optimization
|
$
|
633
|
$
|
413
|
$
|
220
|
53
|
%
|
|||||
Fluid
Systems
|
348
|
251
|
97
|
39
|
|||||||||
Drilling
and Formation Evaluation
|
225
|
177
|
48
|
27
|
|||||||||
Digital
and Consulting Solutions
|
60
|
(15
|
)
|
75
|
NM
|
||||||||
Total
Energy Services Group
|
1,266
|
826
|
440
|
53
|
|||||||||
Government
and Infrastructure
|
84
|
194
|
(110
|
)
|
(57
|
)
|
|||||||
Energy
and Chemicals
|
(426
|
)
|
(225
|
)
|
(201
|
)
|
(89
|
)
|
|||||
Shared
KBR
|
-
|
(5
|
)
|
5
|
100
|
||||||||
Total
KBR
|
(342
|
)
|
(36
|
)
|
(306
|
)
|
NM
|
||||||
General
corporate
|
(87
|
)
|
(70
|
)
|
(17
|
)
|
(24
|
)
|
|||||
Total
operating
income (loss)
|
$
|
837
|
$
|
720
|
$
|
117
|
16
|
%
|
|||||
Geographic
- Energy Services Group segments only:
|
|||||||||||||
Production
Optimization:
|
|||||||||||||
North
America
|
$
|
376
|
$
|
194
|
$
|
182
|
94
|
%
|
|||||
Latin
America
|
56
|
75
|
(19
|
)
|
(25
|
)
|
|||||||
Europe/Africa/CIS
|
110
|
48
|
62
|
129
|
|||||||||
Middle
East/Asia
|
91
|
96
|
(5
|
)
|
(5
|
)
|
|||||||
Subtotal
|
633
|
413
|
220
|
53
|
|||||||||
Fluid
Systems:
|
|||||||||||||
North
America
|
186
|
104
|
82
|
79
|
|||||||||
Latin
America
|
55
|
52
|
3
|
6
|
|||||||||
Europe/Africa/CIS
|
70
|
58
|
12
|
21
|
|||||||||
Middle
East/Asia
|
37
|
37
|
-
|
-
|
|||||||||
Subtotal
|
348
|
251
|
97
|
39
|
|||||||||
Drilling
and Formation Evaluation:
|
|||||||||||||
North
America
|
102
|
60
|
42
|
70
|
|||||||||
Latin
America
|
24
|
30
|
(6
|
)
|
(20
|
)
|
|||||||
Europe/Africa/CIS
|
39
|
30
|
9
|
30
|
|||||||||
Middle
East/Asia
|
60
|
57
|
3
|
5
|
|||||||||
Subtotal
|
225
|
177
|
48
|
27
|
|||||||||
Digital
and Consulting Solutions:
|
|||||||||||||
North
America
|
58
|
(52
|
)
|
110
|
212
|
||||||||
Latin
America
|
(5
|
)
|
8
|
(13
|
)
|
(163
|
)
|
||||||
Europe/Africa/CIS
|
(5
|
)
|
16
|
(21
|
)
|
(131
|
)
|
||||||
Middle
East/Asia
|
12
|
13
|
(1
|
)
|
(8
|
)
|
|||||||
Subtotal
|
60
|
(15
|
)
|
75
|
NM
|
||||||||
Total
Energy Services Group
|
|||||||||||||
operating
income by region:
|
|||||||||||||
North
America
|
722
|
306
|
416
|
136
|
|||||||||
Latin
America
|
130
|
165
|
(35
|
)
|
(21
|
)
|
|||||||
Europe/Africa/CIS
|
214
|
152
|
62
|
41
|
|||||||||
Middle
East/Asia
|
200
|
203
|
(3
|
)
|
(1
|
)
|
|||||||
Total
Energy Services Group
|
|||||||||||||
operating
income
|
$
|
1,266
|
$
|
826
|
$
|
440
|
53
|
%
|
-
|
percentage-of-completion
accounting for contracts to provide construction, engineering, design,
or
similar services;
|
-
|
accounting
for government contracts;
|
-
|
allowance
for bad debts;
|
-
|
forecasting
our effective tax rate, including our future ability to utilize foreign
tax credits and the realizability of deferred tax
assets;
|
-
|
legal
and investigation matters; and
|
-
|
pensions.
|
-
|
estimates
of the total cost to complete the
project;
|
-
|
estimates
of project schedule and completion
date;
|
-
|
estimates
of the percentage the project is complete;
and
|
-
|
amounts
of any probable unapproved claims and change orders included in
revenue.
|
-
|
a
current tax liability or asset is recognized for the estimated taxes
payable or refundable on tax returns for the current
year;
|
-
|
a
deferred tax liability or asset is recognized for the estimated future
tax
effects attributable to temporary differences and
carryforwards;
|
-
|
the
measurement of current and deferred tax liabilities and assets is
based on
provisions of the enacted tax law, and the effects of potential future
changes in tax laws or rates are not considered;
and
|
-
|
the
value of deferred tax assets is reduced, if necessary, by the amount
of
any tax benefits that, based on available evidence, are not expected
to be
realized.
|
-
|
identifying
the types and amounts of existing temporary
differences;
|
-
|
measuring
the total deferred tax liability for taxable temporary differences
using
the applicable tax rate;
|
-
|
measuring
the total deferred tax asset for deductible temporary differences
and
operating loss carryforwards using the applicable tax
rate;
|
-
|
measuring
the deferred tax assets for each type of tax credit carryforward;
and
|
-
|
reducing
the deferred tax assets by a valuation allowance if, based on available
evidence, it is more likely than not that some portion or all of
the
deferred tax assets will not be
realized.
|
-
|
volatility
of the currency rates;
|
-
|
time
horizon of the derivative
instruments;
|
-
|
market
cycles; and
|
-
|
the
type of derivative instruments
used.
|
Millions
of dollars
|
2006
|
2007
|
2008
|
2009
|
2010
|
Thereafter
|
Total
|
|||||||||||||||
Fixed-rate
debt:
|
||||||||||||||||||||||
Repayment
amount ($US)
|
$
|
275
|
$
|
-
|
$
|
150
|
$
|
-
|
$
|
750
|
$
|
1,875
|
$
|
3,050
|
||||||||
Weighted
average interest
|
||||||||||||||||||||||
rate
on repaid amount
|
6.0
|
%
|
-
|
5.6
|
%
|
-
|
5.5
|
%
|
4.8
|
%
|
5.1
|
%
|
||||||||||
Variable-rate
debt:
|
||||||||||||||||||||||
Repayment
amount ($US)
|
$
|
68
|
$
|
16
|
$
|
2
|
$
|
-
|
$
|
-
|
$
|
-
|
$
|
86
|
||||||||
Weighted
average interest
|
||||||||||||||||||||||
rate
on repaid amount
|
6.9
|
%
|
5.7
|
%
|
6.0
|
%
|
-
|
-
|
-
|
6.7
|
%
|
-
|
the
Comprehensive Environmental Response, Compensation, and Liability
Act;
|
-
|
the
Resources Conservation and Recovery
Act;
|
-
|
the
Clean Air Act;
|
-
|
the
Federal Water Pollution Control Act;
and
|
-
|
the
Toxic Substances Control Act.
|
-
|
expropriation
and nationalization of our assets in that
country;
|
-
|
political
and economic instability;
|
-
|
civil
unrest, acts of terrorism, force majeure, war, or other armed
conflict;
|
-
|
natural
disasters, including those related to earthquakes and
flooding;
|
-
|
inflation;
|
-
|
currency
fluctuations, devaluations, and conversion
restrictions;
|
-
|
confiscatory
taxation or other adverse tax
policies;
|
-
|
governmental
activities that limit or disrupt markets, restrict payments, or limit
the
movement of funds;
|
-
|
governmental
activities that may result in the deprivation of contract rights;
and
|
-
|
governmental
activities that may result in the inability to obtain or retain licenses
required for operation.
|
-
|
foreign
exchange risks resulting from changes in foreign exchange rates and
the
implementation of exchange controls;
and
|
-
|
limitations
on our ability to reinvest earnings from operations in one country
to fund
the capital needs of our operations in other
countries.
|
-
|
adverse
movements in foreign exchange
rates;
|
-
|
interest
rates;
|
-
|
commodity
prices; or
|
-
|
the
value and time period of the derivative being different than the
exposures
or cash flows being hedged.
|
-
|
governmental
regulations, including the policies of governments regarding the
exploration for and production and development of their oil and natural
gas reserves;
|
-
|
global
weather conditions and natural
disasters;
|
-
|
worldwide
political, military, and economic
conditions;
|
-
|
the
level of oil production by non-OPEC countries and the available excess
production capacity within OPEC;
|
-
|
economic
growth in China and India;
|
-
|
oil
refining capacity and shifts in end-customer preferences toward fuel
efficiency and the use of natural
gas;
|
-
|
the
cost of producing and delivering oil and
gas;
|
-
|
potential
acceleration of development of alternative fuels;
and
|
-
|
the
level of demand for oil and natural gas, especially demand for natural
gas
in the United States.
|
-
|
a
decrease in the magnitude of governmental spending and outsourcing
for
military and logistical support of the type that we provide. For
example,
the current level of government services being provided in the Middle
East
will not likely continue for an extended period of time and the current
rate of spending has decreased substantially compared to 2005 and
2004. We
expect the volume of work under our LogCAP contract to continue to
decline
in 2006 as our customer scales back the amount of services we provide.
The
government can terminate, reduce the amount of work, or replace our
LogCAP
contract with a new competitively bid contract at anytime during
the term
of the contract;
|
-
|
an
increase in the magnitude of governmental spending and outsourcing
for
military and logistical support, which can materially and adversely
affect
our liquidity needs as a result of additional or continued working
capital
requirements to support this work;
|
-
|
a
decrease in capital spending by governments for infrastructure projects
of
the type that we undertake;
|
-
|
the
consolidation of our customers, which
could:
|
-
|
cause
customers to reduce their capital spending, which would in turn reduce
the
demand for our services and products;
and
|
-
|
result
in customer personnel changes, which in turn affects the timing of
contract negotiations and settlements of claims and claim negotiations
with engineering and construction customers on cost variances and
change
orders on major projects;
|
-
|
adverse
developments in the business and operations of our customers in the
oil
and gas industry, including write-downs of reserves and reductions
in
capital spending for exploration, development, production, processing,
refining, and pipeline delivery networks;
and
|
-
|
ability
of our customers to timely pay the amounts due
us.
|
-
|
any
acquisitions would result in an increase in
income;
|
-
|
any
acquisitions would be successfully integrated into our operations
and
internal controls;
|
-
|
any
disposition would not result in decreased earnings, revenue, or cash
flow;
|
-
|
any
dispositions, investments, acquisitions, or integrations would not
divert
management resources; or
|
-
|
any
dispositions, investments, acquisitions, or integrations would not
have a
material adverse effect on our results of operations or financial
condition.
|
-
|
the
containment and disposal of hazardous substances, oilfield waste,
and
other waste materials;
|
-
|
the
importation and use of radioactive
materials;
|
-
|
the
use of underground storage tanks;
and
|
-
|
the
use of underground injection wells.
|
-
|
administrative,
civil, and criminal penalties;
|
-
|
revocation
of permits to conduct business; and
|
-
|
corrective
action orders, including orders to investigate and/or clean-up
contamination.
|
-
|
evacuation
of personnel and curtailment of
services;
|
-
|
weather-related
damage to offshore drilling rigs resulting in suspension of
operations;
|
-
|
weather-related
damage to our facilities;
|
-
|
inability
to deliver materials to jobsites in accordance with contract schedules;
and
|
-
|
loss
of productivity.
|
/s/ David J. Lesar
|
/s/ C.
Christopher Gaut
|
David
J. Lesar
|
C.
Christopher Gaut
|
Chairman
of the Board,
|
Executive
Vice President and
|
President,
and
|
Chief
Financial Officer
|
Chief
Executive Officer
|
Years
ended December 31
|
||||||||||
Millions
of dollars and shares except per share data
|
2005
|
2004
|
2003
|
|||||||
Revenue:
|
||||||||||
Services
|
$
|
18,420
|
$
|
18,327
|
$
|
14,383
|
||||
Product
sales
|
2,587
|
2,137
|
1,863
|
|||||||
Equity
in earnings (losses) of unconsolidated affiliates, net
|
(13
|
)
|
2
|
25
|
||||||
Total
revenue
|
20,994
|
20,466
|
16,271
|
|||||||
Operating
costs and expenses:
|
||||||||||
Cost
of services
|
16,017
|
17,441
|
13,589
|
|||||||
Cost
of sales
|
2,129
|
1,882
|
1,679
|
|||||||
General
and administrative
|
380
|
361
|
330
|
|||||||
Gain
on sale of business assets, net
|
(194
|
)
|
(55
|
)
|
(47
|
)
|
||||
Total
operating costs and expenses
|
18,332
|
19,629
|
15,551
|
|||||||
Operating
income
|
2,662
|
837
|
720
|
|||||||
Interest
expense
|
(207
|
)
|
(229
|
)
|
(139
|
)
|
||||
Interest
income
|
64
|
44
|
30
|
|||||||
Foreign
currency losses, net
|
(13
|
)
|
(3
|
)
|
-
|
|||||
Other,
net
|
(14
|
)
|
2
|
1
|
||||||
Income
from continuing operations before income taxes,
minority
|
||||||||||
interest,
and change in accounting principle
|
2,492
|
651
|
612
|
|||||||
Provision
for income taxes
|
(79
|
)
|
(241
|
)
|
(234
|
)
|
||||
Minority
interest in net income of subsidiaries
|
(56
|
)
|
(25
|
)
|
(39
|
)
|
||||
Income
from continuing operations before change in
accounting
|
||||||||||
principle
|
2,357
|
385
|
339
|
|||||||
Income
(loss) from discontinued operations, net of tax (provision)
benefit
|
||||||||||
of
$(1), $180, and $(6)
|
1
|
(1,364
|
)
|
(1,151
|
)
|
|||||
Cumulative
effect of change in accounting principle, net of tax benefit of
$5
|
-
|
-
|
(8
|
)
|
||||||
Net
income (loss)
|
$
|
2,358
|
$
|
(979
|
)
|
$
|
(820
|
)
|
||
Basic
income (loss) per share:
|
||||||||||
Income
from continuing operations before change in accounting
principle
|
$
|
4.67
|
$
|
0.88
|
$
|
0.78
|
||||
Income
(loss) from discontinued operations, net
|
-
|
(3.13
|
)
|
(2.65
|
)
|
|||||
Cumulative
effect of change in accounting principle, net
|
-
|
-
|
(0.02
|
)
|
||||||
Net
income (loss)
|
$
|
4.67
|
$
|
(2.25
|
)
|
$
|
(1.89
|
)
|
||
Diluted
income (loss) per share:
|
||||||||||
Income
from continuing operations before change in accounting
principle
|
$
|
4.54
|
$
|
0.87
|
$
|
0.78
|
||||
Income
(loss) from discontinued operations, net
|
-
|
(3.09
|
)
|
(2.64
|
)
|
|||||
Cumulative
effect of change in accounting principle, net
|
-
|
-
|
(0.02
|
)
|
||||||
Net
income (loss)
|
$
|
4.54
|
$
|
(2.22
|
)
|
$
|
(1.88
|
)
|
||
Basic
weighted average common shares outstanding
|
505
|
437
|
434
|
|||||||
Diluted
weighted average common shares outstanding
|
519
|
441
|
437
|
December
31
|
|||||||
Millions
of dollars and shares except per share data
|
2005
|
2004
|
|||||
Assets
|
|||||||
Current
assets:
|
|||||||
Cash
and equivalents
|
$
|
2,391
|
$
|
1,917
|
|||
Investments
in marketable securities
|
-
|
891
|
|||||
Receivables:
|
|||||||
Notes
and accounts receivable (less allowance for bad debts of $90 and
$127)
|
3,152
|
2,873
|
|||||
Unbilled
work on uncompleted contracts
|
1,456
|
1,812
|
|||||
Insurance
for asbestos- and silica-related liabilities
|
193
|
1,066
|
|||||
Total
receivables
|
4,801
|
5,751
|
|||||
Inventories
|
953
|
791
|
|||||
Current
deferred income taxes
|
592
|
301
|
|||||
Other
current assets
|
590
|
379
|
|||||
Total
current assets
|
9,327
|
10,030
|
|||||
Property,
plant, and equipment, net of accumulated depreciation of $3,838
and
$3,674
|
2,648
|
2,553
|
|||||
Noncurrent
deferred income taxes
|
838
|
780
|
|||||
Goodwill
|
765
|
795
|
|||||
Equity
in and advances to related companies
|
382
|
541
|
|||||
Insurance
for asbestos- and silica-related liabilities
|
203
|
350
|
|||||
Other
assets
|
847
|
815
|
|||||
Total
assets
|
$
|
15,010
|
$
|
15,864
|
|||
Liabilities
and Shareholders’ Equity
|
|||||||
Current
liabilities:
|
|||||||
Accounts
payable
|
$
|
1,967
|
$
|
2,339
|
|||
Advanced
billings on uncompleted contracts
|
661
|
553
|
|||||
Accrued
employee compensation and benefits
|
648
|
473
|
|||||
Current
maturities of long-term debt
|
361
|
347
|
|||||
Short-term
notes payable
|
22
|
15
|
|||||
Asbestos-
and silica-related liabilities
|
-
|
2,408
|
|||||
Other
current liabilities
|
778
|
997
|
|||||
Total
current liabilities
|
4,437
|
7,132
|
|||||
Long-term
debt
|
2,813
|
3,593
|
|||||
Employee
compensation and benefits
|
718
|
635
|
|||||
Other
liabilities
|
525
|
464
|
|||||
Total
liabilities
|
8,493
|
11,824
|
|||||
Minority
interest in consolidated subsidiaries
|
145
|
108
|
|||||
Shareholders’
equity:
|
|||||||
Common
shares, par value $2.50 per share - authorized 1,000 shares, issued
527
and 458 shares
|
1,317
|
1,146
|
|||||
Paid-in
capital in excess of par value
|
2,818
|
277
|
|||||
Common
shares to be contributed to asbestos trust - 59.5 shares
|
-
|
2,335
|
|||||
Deferred
compensation
|
(98
|
)
|
(74
|
)
|
|||
Accumulated
other comprehensive income
|
(266
|
)
|
(146
|
)
|
|||
Retained
earnings
|
2,975
|
871
|
|||||
6,746
|
4,409
|
||||||
Less
13 and 16 shares of treasury stock, at cost
|
374
|
477
|
|||||
Total
shareholders’ equity
|
6,372
|
3,932
|
|||||
Total
liabilities and shareholders’ equity
|
$
|
15,010
|
$
|
15,864
|
Millions
of dollars and shares
|
2005
|
2004
|
2003
|
|||||||
Balance
at January 1
|
$
|
3,932
|
$
|
2,547
|
$
|
3,558
|
||||
Dividends
and other transactions with shareholders
|
202
|
(123
|
)
|
(174
|
)
|
|||||
Common
shares to be contributed to asbestos
|
||||||||||
trust
- 59.5 shares
|
-
|
2,335
|
-
|
|||||||
Comprehensive
income (loss):
|
||||||||||
Net
income (loss)
|
2,358
|
(979
|
)
|
(820
|
)
|
|||||
Cumulative
translation adjustments
|
(48
|
)
|
33
|
43
|
||||||
Realization
of (gains) losses included in net
|
||||||||||
income
(loss)
|
7
|
(1
|
)
|
15
|
||||||
Net
cumulative translation adjustments
|
(41
|
)
|
32
|
58
|
||||||
Pension
liability adjustments
|
(54
|
)
|
115
|
(88
|
)
|
|||||
Unrealized
gains (losses) on investments and
|
||||||||||
derivatives
|
(12
|
)
|
5
|
13
|
||||||
Realization
of gains on investments and
|
||||||||||
derivatives
|
(13
|
)
|
-
|
-
|
||||||
Net
unrealized gains (losses) on investments
|
||||||||||
and
derivatives
|
(25
|
)
|
5
|
13
|
||||||
Total
comprehensive income (loss)
|
2,238
|
(827
|
)
|
(837
|
)
|
|||||
Balance
at December 31
|
$
|
6,372
|
$
|
3,932
|
$
|
2,547
|
Years
ended December 31
|
||||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Cash
flows from operating activities:
|
||||||||||
Net
income (loss)
|
$
|
2,358
|
$
|
(979
|
)
|
$
|
(820
|
)
|
||
Adjustments
to reconcile net income (loss) to net cash from
operations:
|
||||||||||
(Income)
loss from discontinued operations
|
(1
|
)
|
1,364
|
1,151
|
||||||
Depreciation,
depletion, and amortization
|
504
|
509
|
518
|
|||||||
Provision
(benefit) for deferred income taxes, including $0, $(167), and
$27
|
||||||||||
related
to discontinued operations
|
(235
|
)
|
(176
|
)
|
(86
|
)
|
||||
Distributions
from (advances to) related companies, net of equity in
|
|
|
|
|
||||||
(earnings) losses | 39 | (39 | ) | 13 | ||||||
Change
in accounting principle, net
|
-
|
-
|
8
|
|||||||
Gain
on sale of assets
|
(192
|
)
|
(62
|
)
|
(52
|
)
|
||||
Asbestos
and silica liability payment related to Chapter 11 filing
|
(2,345
|
)
|
(119
|
)
|
(311
|
)
|
||||
Collection
of asbestos- and silica-related insurance receivables
|
1,032
|
-
|
-
|
|||||||
Other
changes:
|
||||||||||
Receivables
and unbilled work on uncompleted contracts
|
423
|
(506
|
)
|
(1,442
|
)
|
|||||
Accounts
receivable facilities transactions
|
(519
|
)
|
519
|
(180
|
)
|
|||||
Inventories
|
(152
|
)
|
(33
|
)
|
(50
|
)
|
||||
Accounts
payable
|
(317
|
)
|
439
|
733
|
||||||
Other
|
106
|
11
|
(257
|
)
|
||||||
Total
cash flows from operating activities
|
701
|
928
|
(775
|
)
|
||||||
Cash
flows from investing activities:
|
||||||||||
Capital
expenditures
|
(651
|
)
|
(575
|
)
|
(515
|
)
|
||||
Sales
of property, plant, and equipment
|
132
|
166
|
107
|
|||||||
Dispositions
of business assets, net of cash disposed
|
299
|
127
|
230
|
|||||||
Acquisitions
of business assets, net of cash acquired
|
(108
|
)
|
(25
|
)
|
(6
|
)
|
||||
Proceeds
from sales of securities
|
15
|
22
|
57
|
|||||||
Sales
(purchases) of short-term investments in marketable securities,
net
|
891
|
(180
|
)
|
(576
|
)
|
|||||
Investments
- restricted cash
|
1
|
89
|
(18
|
)
|
||||||
Other
investing activities
|
(69
|
)
|
(30
|
)
|
(51
|
)
|
||||
Total
cash flows from investing activities
|
510
|
(406
|
)
|
(772
|
)
|
|||||
Cash
flows from financing activities:
|
||||||||||
Proceeds
from long-term debt, net of offering costs
|
24
|
496
|
2,192
|
|||||||
Proceeds
from exercises of stock options
|
342
|
63
|
21
|
|||||||
Payments
to reacquire common stock
|
(12
|
)
|
(7
|
)
|
(6
|
)
|
||||
Borrowings
(repayments) of short-term debt, net
|
10
|
(7
|
)
|
(32
|
)
|
|||||
Payments
on long-term debt
|
(823
|
)
|
(20
|
)
|
(296
|
)
|
||||
Payments
of dividends to shareholders
|
(254
|
)
|
(221
|
)
|
(219
|
)
|
||||
Other
financing activities
|
(7
|
)
|
(21
|
)
|
(24
|
)
|
||||
Total
cash flows from financing activities
|
(720
|
)
|
283
|
1,636
|
||||||
Effect
of exchange rate changes on cash
|
(17
|
)
|
8
|
43
|
||||||
Increase
in cash and equivalents
|
474
|
813
|
132
|
|||||||
Cash
and equivalents at beginning of year
|
1,917
|
1,104
|
972
|
|||||||
Cash
and equivalents at end of year
|
$
|
2,391
|
$
|
1,917
|
$
|
1,104
|
||||
Supplemental
disclosure of cash flow information:
|
||||||||||
Cash
payments during the year for:
|
||||||||||
Interest
|
$
|
210
|
$
|
211
|
$
|
114
|
||||
Income
taxes
|
$
|
282
|
$
|
265
|
$
|
173
|
-
|
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 revenue and expenses during the reporting
period.
|
-
|
the
change in fair value of the hedged assets, liabilities, or firm
commitments through earnings; or
|
-
|
recognized
in other comprehensive income until the hedged item is recognized
in
earnings.
|
Assumptions
|
Weighted
Average
|
|||||||||||||||
|
Expected
|
|
|
Fair
Value of
|
||||||||||||
Risk-Free
Interest
Rate
|
Dividend
Yield
|
Expected
Life
(in years)
|
Expected
Volatility
|
Options
Granted
|
||||||||||||
2005
|
4.3
|
%
|
0.8
|
%
|
5
|
51
|
%
|
$
|
22.83
|
|||||||
2004
|
3.7
|
%
|
1.3
|
%
|
5
|
54
|
%
|
$
|
13.37
|
|||||||
2003
|
3.2
|
%
|
1.9
|
%
|
5
|
59
|
%
|
$
|
12.37
|
Years
ended December 31
|
||||||||||
Millions
of dollars except per share data
|
2005
|
2004
|
2003
|
|||||||
Net
income (loss), as reported
|
$
|
2,358
|
$
|
(979
|
)
|
$
|
(820
|
)
|
||
Total
stock-based employee compensation
|
||||||||||
expense
determined under fair value
|
||||||||||
based
method for all awards (except
|
||||||||||
restricted
stock), net of related tax
|
||||||||||
effects
|
(30
|
)
|
(28
|
)
|
(30
|
)
|
||||
Net
income (loss), pro forma
|
$
|
2,328
|
$
|
(1,007
|
)
|
$
|
(850
|
)
|
||
Basic
income (loss) per share:
|
||||||||||
As
reported
|
$
|
4.67
|
$
|
(2.25
|
)
|
$
|
(1.89
|
)
|
||
Pro
forma
|
$
|
4.61
|
$
|
(2.31
|
)
|
$
|
(1.96
|
)
|
||
Diluted
income (loss) per share:
|
||||||||||
As
reported
|
$
|
4.54
|
$
|
(2.22
|
)
|
$
|
(1.88
|
)
|
||
Pro
forma
|
$
|
4.49
|
$
|
(2.28
|
)
|
$
|
(1.95
|
)
|
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Probable
unapproved claims
|
$
|
175
|
$
|
182
|
$
|
233
|
||||
Probable
unapproved claims accrued revenue
|
172
|
182
|
225
|
|||||||
Probable
unapproved claims from unconsolidated related companies
|
92
|
51
|
10
|
-
|
the
project was approximately 98%
complete;
|
-
|
we
recorded losses on this project of $407 million in 2004 and $238
million
in 2003;
|
-
|
the
losses recorded include $22 million in liquidated damages paid in
2004
based on our agreement with
Petrobras;
|
-
|
the
$300 million of advance payments received from our customer have
been
completely repaid; and
|
-
|
we
have received $138 million related to approved change
orders.
|
-
|
cementing
services, which involve the process used to bond the well and well
casing
while isolating fluid zones and maximizing wellbore stability. Our
cementing service line also provides casing equipment and
services;
|
-
|
Baroid
Fluid Services, which provides drilling fluid systems, performance
additives, solids control, and waste management services for oil
and gas
drilling, completion, and workover operations;
and
|
-
|
Enventure,
an expandable casing joint venture, which we account for using the
cost
method.
|
-
|
Sperry
Drilling Services, which provides drilling systems and services.
These
services include directional and horizontal drilling,
measurement-while-drilling, logging-while-drilling, multilateral
systems,
and rig site information systems. Our drilling systems offer directional
control while providing important measurements about the characteristics
of the drill string and geological formations while drilling directional
wells. Real-time operating capabilities enable the monitoring of
well
progress and aid decision-making
processes;
|
-
|
Security
DBS Drill Bits, which provides roller cone rock bits, fixed cutter
bits,
and related downhole tools used in drilling oil and gas wells. In
addition, coring equipment and services are provided to acquire cores
of
the formation drilled for evaluation;
and
|
-
|
logging
services, which include open-hole wireline services that provide
information on formation evaluation, including resistivity, porosity,
and
density, rock mechanics, and fluid sampling. Also offered are cased-hole
services, which provide cement bond evaluation, reservoir monitoring,
pipe
evaluation, pipe recovery, and
perforating.
|
-
|
downstream
engineering and construction capabilities, including global engineering
execution centers, as well as engineering, construction, and program
management of liquefied natural gas, ammonia, petrochemicals, crude
oil
refineries, and natural gas plants;
|
-
|
upstream
deepwater engineering, marine technology, and project
management;
|
-
|
plant
operations, maintenance, and start-up services for both upstream
and
downstream oil and gas facilities worldwide, as well as maintenance
services for the petrochemical, forest product, power, and commercial
markets;
|
-
|
industry-leading
licensed technologies in the areas of fertilizers and synthesis gas,
olefins, refining, and chemicals and polymers;
and
|
-
|
consulting
services in the form of expert technical and management advice that
include studies, conceptual and detailed engineering, project management,
construction supervision and design, and construction verification
or
certification in both upstream and downstream
markets.
|
-
|
TSKJ
is a joint venture company formed to design and construct large scale
projects in Nigeria. TSKJ’s members are Technip, SA of France,
Snamprogetti Netherlands B.V., which is an affiliate of ENI SpA of
Italy,
JGC Corporation of Japan, and KBR, each of which owns 25%. TSKJ has
completed five LNG production facilities on Bonny Island, Nigeria
and is
currently working on a sixth such facility. We account for this investment
under the equity method.
|
-
|
M.
W. Kellogg Limited (MWKL) is a London-based joint venture that provides
full engineering, procurement, and construction contractor services
for
LNG, gas-to-liquids, and onshore oil and gas projects. MWKL is owned
55%
by KBR and 45% by JGC Corporation. We consolidate MWKL for financial
reporting purposes.
|
Operations
by business segment
|
||||||||||
Years
ended December 31
|
||||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Revenue:
|
||||||||||
Production
Optimization
|
$
|
4,284
|
$
|
3,303
|
$
|
2,758
|
||||
Fluid
Systems
|
2,838
|
2,324
|
2,039
|
|||||||
Drilling
and Formation Evaluation
|
2,258
|
1,782
|
1,643
|
|||||||
Digital
and Consulting Solutions
|
720
|
589
|
555
|
|||||||
Total
Energy Services Group
|
10,100
|
7,998
|
6,995
|
|||||||
Government
and Infrastructure
|
8,148
|
9,393
|
5,417
|
|||||||
Energy
and Chemicals
|
2,746
|
3,075
|
3,859
|
|||||||
Total
KBR
|
10,894
|
12,468
|
9,276
|
|||||||
Total
|
$
|
20,994
|
$
|
20,466
|
$
|
16,271
|
||||
Operating
income (loss):
|
||||||||||
Production
Optimization
|
$
|
1,106
|
$
|
633
|
$
|
413
|
||||
Fluid
Systems
|
544
|
348
|
251
|
|||||||
Drilling
and Formation Evaluation
|
483
|
225
|
177
|
|||||||
Digital
and Consulting Solutions
|
146
|
60
|
(15
|
)
|
||||||
Total
Energy Services Group
|
2,279
|
1,266
|
826
|
|||||||
Government
and Infrastructure
|
330
|
84
|
194
|
|||||||
Energy
and Chemicals
|
168
|
(426
|
)
|
(225
|
)
|
|||||
Shared
KBR
|
-
|
-
|
(5
|
)
|
||||||
Total
KBR
|
498
|
(342
|
)
|
(36
|
)
|
|||||
General
corporate
|
(115
|
)
|
(87
|
)
|
(70
|
)
|
||||
Total
|
$
|
2,662
|
$
|
837
|
$
|
720
|
||||
Capital
expenditures:
|
||||||||||
Production
Optimization
|
$
|
254
|
$
|
220
|
$
|
161
|
||||
Fluid
Systems
|
94
|
74
|
96
|
|||||||
Drilling
and Formation Evaluation
|
201
|
172
|
169
|
|||||||
Digital
and Consulting Solutions
|
26
|
32
|
27
|
|||||||
Total
Energy Services Group
|
575
|
498
|
453
|
|||||||
Government
and Infrastructure
|
33
|
41
|
45
|
|||||||
Energy
and Chemicals
|
4
|
9
|
5
|
|||||||
Shared
KBR
|
39
|
27
|
12
|
|||||||
Total
KBR
|
76
|
77
|
62
|
|||||||
Total
|
$
|
651
|
$
|
575
|
$
|
515
|
Operations
by business segment (continued)
|
||||||||||
Years
ended December 31
|
||||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Depreciation,
depletion, and amortization:
|
||||||||||
Production
Optimization
|
$
|
165
|
$
|
159
|
$
|
144
|
||||
Fluid
Systems
|
88
|
83
|
77
|
|||||||
Drilling
and Formation Evaluation
|
131
|
139
|
168
|
|||||||
Digital
and Consulting Solutions
|
64
|
75
|
78
|
|||||||
Total
Energy Services Group
|
448
|
456
|
467
|
|||||||
Government
and Infrastructure
|
32
|
27
|
22
|
|||||||
Energy
and Chemicals
|
9
|
11
|
16
|
|||||||
Shared
KBR
|
15
|
15
|
12
|
|||||||
Total
KBR
|
56
|
53
|
50
|
|||||||
General
corporate
|
-
|
-
|
1
|
|||||||
Total
|
$
|
504
|
$
|
509
|
$
|
518
|
||||
Total
assets:
|
||||||||||
Production
Optimization
|
$
|
2,466
|
$
|
2,040
|
$
|
1,962
|
||||
Fluid
Systems
|
1,438
|
1,230
|
1,248
|
|||||||
Drilling
and Formation Evaluation
|
1,328
|
1,126
|
1,254
|
|||||||
Digital
and Consulting Solutions
|
803
|
768
|
794
|
|||||||
Shared
energy services
|
494
|
452
|
596
|
|||||||
Total
Energy Services Group
|
6,529
|
5,616
|
5,854
|
|||||||
Government
and Infrastructure
|
2,645
|
3,309
|
2,758
|
|||||||
Energy
and Chemicals
|
1,957
|
1,656
|
2,078
|
|||||||
Shared
KBR
|
326
|
198
|
246
|
|||||||
Total
KBR
|
4,928
|
5,163
|
5,082
|
|||||||
General
corporate
|
3,553
|
5,085
|
4,620
|
|||||||
Total
|
$
|
15,010
|
$
|
15,864
|
$
|
15,556
|
Operations
by geographic area
|
||||||||||
Years
ended December 31
|
||||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Revenue:
|
||||||||||
United
States
|
$
|
5,655
|
$
|
4,461
|
$
|
4,415
|
||||
Iraq
|
5,116
|
5,362
|
2,399
|
|||||||
United
Kingdom
|
2,013
|
1,646
|
1,473
|
|||||||
Kuwait
|
416
|
1,841
|
856
|
|||||||
Other
countries
|
7,794
|
7,156
|
7,128
|
|||||||
Total
|
$
|
20,994
|
$
|
20,466
|
$
|
16,271
|
||||
Long-lived
assets:
|
||||||||||
United
States
|
$
|
2,409
|
$
|
2,485
|
$
|
4,461
|
||||
United
Kingdom
|
563
|
697
|
630
|
|||||||
Other
countries
|
1,300
|
1,126
|
917
|
|||||||
Total
|
$
|
4,272
|
$
|
4,308
|
$
|
6,008
|
December
31
|
|||||||
Millions
of dollars
|
2005
|
2004
|
|||||
Finished
products and parts
|
$
|
715
|
$
|
602
|
|||
Raw
materials and supplies
|
181
|
156
|
|||||
Work
in process
|
57
|
33
|
|||||
Total
|
$
|
953
|
$
|
791
|
-
|
$100
million as collateral for potential future insurance claim reimbursements;
and
|
-
|
$23
million related to cash collateral agreements for outstanding letters
of
credit for various construction
projects.
|
Millions
of dollars
|
2005
|
2004
|
|||||
Land
|
$
|
66
|
$
|
68
|
|||
Buildings
and property improvements
|
940
|
1,088
|
|||||
Machinery,
equipment, and other
|
5,480
|
5,071
|
|||||
Total
|
6,486
|
6,227
|
|||||
Less
accumulated depreciation
|
3,838
|
3,674
|
|||||
Net
property, plant, and equipment
|
$
|
2,648
|
$
|
2,553
|
Buildings
and Property
|
|||||||
Improvements
|
|||||||
2005
|
2004
|
||||||
1-10
years
|
25
|
%
|
19
|
%
|
|||
11-20
years
|
45
|
%
|
45
|
%
|
|||
21-30
years
|
11
|
%
|
16
|
%
|
|||
31-40
years
|
19
|
%
|
20
|
%
|
Machinery,
Equipment,
|
|||||||
and
Other
|
|||||||
2005
|
2004
|
||||||
1-5
years
|
25
|
%
|
28
|
%
|
|||
6-10
years
|
69
|
%
|
63
|
%
|
|||
11-20
years
|
6
|
%
|
9
|
%
|
Millions
of dollars
|
2005
|
2004
|
|||||
3.125%
convertible senior notes due July 2023
|
$
|
1,200
|
$
|
1,200
|
|||
5.5%
senior notes due October 2010
|
748
|
748
|
|||||
Medium-term
notes due 2006 thru 2027
|
600
|
600
|
|||||
7.6%
debentures of Halliburton due August 2096
|
294
|
294
|
|||||
8.75%
debentures due February 2021
|
200
|
200
|
|||||
0.75%
plus three-month LIBOR senior notes repaid in April 2005
|
-
|
500
|
|||||
1.5%
plus three-month LIBOR senior notes repaid in October 2005
|
-
|
300
|
|||||
Other
|
132
|
98
|
|||||
Total
long-term debt
|
3,174
|
3,940
|
|||||
Less
current portion
|
361
|
347
|
|||||
Noncurrent
portion of long-term debt
|
$
|
2,813
|
$
|
3,593
|
-
|
during
any calendar quarter if the last reported sale price of our common
stock
for at least 20 trading days during the period of 30 consecutive
trading
days ending on the last trading day of the previous quarter is greater
than or equal to 120% of the conversion price per share of our common
stock on such last trading day. This circumstance was achieved in
the
third and fourth quarters of 2005. There were no conversions of these
notes as of February 15, 2006;
|
-
|
if
the notes have been called for
redemption;
|
-
|
upon
the occurrence of specified corporate transactions that are described
in
the indenture relating to the offering;
or
|
-
|
during
any period in which the credit ratings assigned to the notes by both
Moody’s Investors Service and Standard & Poor’s are lower than Ba1 and
BB+, respectively, or the notes are no longer rated by at least one
of
these rating services or their
successors.
|
Amount
|
|||||||
Due
|
Rate
|
(in
millions)
|
|||||
08/2006
|
6.00
|
%
|
$
|
275
|
|||
12/2008
|
5.63
|
%
|
$
|
150
|
|||
05/2017
|
7.53
|
%
|
$
|
50
|
|||
02/2027
|
6.75
|
%
|
$
|
125
|
-
|
asbestos
used in products manufactured or sold by former divisions of DII
Industries (primarily refractory materials, gaskets, and packing
materials
used in pumps and other industrial
products);
|
-
|
asbestos
in materials used in the construction and maintenance projects of
Kellogg
Brown & Root or its subsidiaries;
and
|
-
|
silica
related to sandblasting and drilling fluids
operations.
|
Millions
of dollars
|
||||
Asbestos-
and silica-related liabilities:
|
||||
December
31, 2004 balance (of which $2,408 was current)
|
$
|
(2,445
|
)
|
|
Payment
to trusts in accordance with the plan of reorganization
|
2,345
|
|||
First
installment payment of partitioning agreement
|
16
|
|||
Cash
settlement payment to the silica trust
|
15
|
|||
Payment
on one-year asbestos note
|
8
|
|||
Reclassification
of remaining note balances to other current liabilities
|
||||
and
long-term debt
|
61
|
|||
Asbestos-
and silica-related liabilities - December 31, 2005 balance
|
$
|
-
|
||
Insurance
for asbestos- and silica-related liabilities:
|
||||
December
31, 2004 balance (of which $1,066 was current)
|
$
|
1,416
|
||
Payments
received
|
(1,032
|
)
|
||
Accretion
|
15
|
|||
Other
|
(3
|
)
|
||
Insurance
for asbestos- and silica-related liabilities - December 31,
2005
|
||||
balance
(of which $193 is current)
|
$
|
396
|
-
|
approximately
$2.345 billion in cash, which represents the remaining portion of
the
$2.775 billion total cash settlement after payments of $311 million
in
December 2003 and $119 million in June
2004;
|
-
|
59.5
million shares of Halliburton common
stock;
|
-
|
a
one-year non-interest-bearing note of $31 million for the benefit
of
asbestos claimants. We prepaid the initial installment on the note
of
approximately $8 million in January 2005 and paid an additional $15
million during the third quarter of 2005. The final payment on the
note of
approximately $8 million was made in the fourth quarter of 2005;
and
|
-
|
a
silica note for the benefit of silica claimants. The note provides
that we
will contribute an amount to the silica trust at the end of each
year for
the next 30 years of up to $15 million. The note also provides for
an
extension of the note for 20 additional years under certain circumstances.
As of December 31, 2005, we estimated the value of this note plus
the
initial cash payment of $15 million, paid in January 2005, to be
approximately $24 million. We will periodically reassess our valuation
of
this note based upon our projections of the amounts we believe we
will be
required to fund into the silica
trust.
|
-
|
the
Comprehensive Environmental Response, Compensation, and Liability
Act;
|
-
|
the
Resources Conservation and Recovery
Act;
|
-
|
the
Clean Air Act;
|
-
|
the
Federal Water Pollution Control Act;
and
|
-
|
the
Toxic Substances Control Act.
|
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Rental
expense
|
$
|
721
|
$
|
693
|
$
|
451
|
Years
ended December 31
|
||||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Current
income taxes:
|
||||||||||
Federal
|
$
|
(106
|
)
|
$
|
(88
|
)
|
$
|
(167
|
)
|
|
Foreign
|
(199
|
)
|
(156
|
)
|
(181
|
)
|
||||
State
|
(9
|
)
|
(6
|
)
|
1
|
|||||
Total
current
|
(314
|
)
|
(250
|
)
|
(347
|
)
|
||||
Deferred
income taxes:
|
||||||||||
Federal
|
305
|
3
|
80
|
|||||||
Foreign
|
(56
|
)
|
6
|
25
|
||||||
State
|
(14
|
)
|
-
|
8
|
||||||
Total
deferred
|
235
|
9
|
113
|
|||||||
Provision
for income taxes
|
$
|
(79
|
)
|
$
|
(241
|
)
|
$
|
(234
|
)
|
Years
ended December 31
|
||||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
United
States
|
$
|
1,721
|
$
|
135
|
$
|
254
|
||||
Foreign
|
771
|
516
|
358
|
|||||||
Total
|
$
|
2,492
|
$
|
651
|
$
|
612
|
Years
ended December 31
|
||||||||||
2005
|
2004
|
2003
|
||||||||
United
States statutory rate
|
35.0
|
%
|
35.0
|
%
|
35.0
|
%
|
||||
State
income taxes, net of federal
|
||||||||||
income
tax benefit
|
1.0
|
0.6
|
0.9
|
|||||||
Impact
of foreign operations
|
(1.2
|
)
|
-
|
0.8
|
||||||
Adjustments
of prior year taxes
|
0.1
|
(2.1
|
)
|
1.6
|
||||||
Dispositions
|
-
|
-
|
(1.6
|
)
|
||||||
Valuation
allowance
|
(32.3
|
)
|
-
|
-
|
||||||
Other
items, net
|
0.5
|
3.6
|
1.5
|
|||||||
Total
effective tax rate on
|
||||||||||
continuing
operations
|
3.1
|
%
|
37.1
|
%
|
38.2
|
%
|
December
31
|
|||||||
Millions
of dollars
|
2005
|
2004
|
|||||
Gross
deferred tax assets:
|
|||||||
Net
operating loss carryforwards
|
$
|
861
|
$
|
115
|
|||
Employee
compensation and benefits
|
299
|
263
|
|||||
Foreign
tax credit carryforward
|
146
|
135
|
|||||
Capitalized
research and experimentation
|
113
|
85
|
|||||
Accrued
liabilities
|
102
|
69
|
|||||
Insurance
accruals
|
58
|
71
|
|||||
Construction
contract accounting
|
41
|
75
|
|||||
Alternative
minimum tax credit carryforward
|
21
|
21
|
|||||
Asbestos-
and silica-related liabilities
|
-
|
1,770
|
|||||
Other
|
291
|
261
|
|||||
Total
gross deferred tax assets
|
$
|
1,932
|
$
|
2,865
|
|||
Gross
deferred tax liabilities:
|
|||||||
Depreciation
and amortization
|
$
|
156
|
$
|
182
|
|||
Insurance
for asbestos- and silica-related
|
|||||||
liabilities
|
-
|
318
|
|||||
Other
|
20
|
33
|
|||||
Total
gross deferred tax liabilities
|
$
|
176
|
$
|
533
|
|||
Valuation
allowances:
|
|||||||
Foreign
tax credit limitation
|
$
|
146
|
$
|
135
|
|||
Future
tax attributes related to United States
|
|||||||
net
operating loss
|
137
|
1,073
|
|||||
Net
operating loss carryforwards
|
43
|
43
|
|||||
Total
valuation allowances
|
$
|
326
|
$
|
1,251
|
|||
Net
deferred income tax asset
|
$
|
1,430
|
$
|
1,081
|
Capital
|
Accumulated
|
||||||||||||||||||
in
Excess
|
Other
|
||||||||||||||||||
Common
|
of
Par
|
Treasury
|
Deferred
|
Retained
|
Comprehensive
|
||||||||||||||
Millions
of dollars
|
Stock
|
Value
|
Stock
|
Compensation
|
Earnings
|
Income
|
|||||||||||||
Balance
at December 31, 2002
|
$
|
1,141
|
$
|
293
|
$
|
(630
|
)
|
$
|
(75
|
)
|
$
|
3,110
|
$
|
(281
|
)
|
||||
Cash
dividends paid
|
-
|
-
|
-
|
-
|
(219
|
)
|
-
|
||||||||||||
Stock-based
compensation and employee
|
|||||||||||||||||||
stock
purchase, net
|
1
|
(19
|
)
|
60
|
11
|
-
|
-
|
||||||||||||
Treasury
stock purchased
|
-
|
-
|
(7
|
)
|
-
|
-
|
-
|
||||||||||||
Tax
benefit from exercise of options and
|
|||||||||||||||||||
restricted
stock
|
-
|
(1
|
)
|
-
|
-
|
-
|
-
|
||||||||||||
Total
dividends and other transactions with
|
|||||||||||||||||||
shareholders
|
1
|
(20
|
)
|
53
|
11
|
(219
|
)
|
-
|
|||||||||||
Comprehensive
income (loss):
|
|||||||||||||||||||
Net
loss
|
-
|
-
|
-
|
-
|
(820
|
)
|
-
|
||||||||||||
Other
comprehensive income:
|
|||||||||||||||||||
Cumulative
translation adjustment
|
-
|
-
|
-
|
-
|
-
|
43
|
|||||||||||||
Realization of losses included in | |||||||||||||||||||
net income
|
-
|
-
|
-
|
-
|
-
|
15
|
|||||||||||||
Minimum
pension liability
|
|||||||||||||||||||
adjustment,
net of tax of $25
|
-
|
-
|
-
|
-
|
-
|
(88
|
)
|
||||||||||||
Net
unrealized gains on
|
|||||||||||||||||||
investments
and derivatives
|
-
|
-
|
-
|
-
|
-
|
13
|
|||||||||||||
Total
comprehensive loss
|
-
|
-
|
-
|
-
|
(820
|
)
|
(17
|
)
|
|||||||||||
Balance
at December 31, 2003
|
$
|
1,142
|
$
|
273
|
$
|
(577
|
)
|
$
|
(64
|
)
|
$
|
2,071
|
$
|
(298
|
)
|
Capital
|
||||||||||||||||||||||
in
|
Accumulated
|
|||||||||||||||||||||
Excess
|
Asbestos
|
Other
|
||||||||||||||||||||
Common
|
of
Par
|
Trust
|
Treasury
|
Deferred
|
Retained
|
Comprehensive
|
||||||||||||||||
Millions
of dollars
|
Stock
|
Value
|
Shares
|
Stock
|
Compensation
|
Earnings
|
Income
|
|||||||||||||||
Balance
at December 31, 2003
|
$
|
1,142
|
$
|
273
|
$
|
-
|
$
|
(577
|
)
|
$
|
(64
|
)
|
$
|
2,071
|
$
|
(298
|
)
|
|||||
Cash
dividends paid
|
-
|
-
|
-
|
-
|
-
|
(221
|
)
|
-
|
||||||||||||||
Stock-based
compensation and
|
||||||||||||||||||||||
employee
stock purchase, net
|
4
|
(3
|
)
|
-
|
107
|
(10
|
)
|
-
|
-
|
|||||||||||||
Treasury
stock purchased
|
-
|
-
|
-
|
(7
|
)
|
-
|
-
|
-
|
||||||||||||||
Tax
benefit from exercise of options and
|
||||||||||||||||||||||
restricted
stock
|
-
|
7
|
-
|
-
|
-
|
-
|
-
|
|||||||||||||||
Total
dividends and other transactions
|
||||||||||||||||||||||
with
shareholders
|
4
|
4
|
-
|
100
|
(10
|
)
|
(221
|
)
|
-
|
|||||||||||||
Asbestos
trust shares
|
-
|
-
|
2,335
|
-
|
-
|
-
|
-
|
|||||||||||||||
Comprehensive
income (loss):
|
||||||||||||||||||||||
Net
loss
|
-
|
-
|
-
|
-
|
-
|
(979
|
)
|
-
|
||||||||||||||
Other
comprehensive income:
|
||||||||||||||||||||||
Cumulative
translation
|
||||||||||||||||||||||
adjustment
|
-
|
-
|
-
|
-
|
-
|
-
|
33
|
|||||||||||||||
Realization
of gains included
|
||||||||||||||||||||||
in
net income
|
-
|
-
|
-
|
-
|
-
|
-
|
(1
|
)
|
||||||||||||||
Minimum
pension liability
|
||||||||||||||||||||||
adjustment,
net of tax of $49
|
-
|
-
|
-
|
-
|
-
|
-
|
115
|
|||||||||||||||
Net
unrealized gains on
|
||||||||||||||||||||||
investments
and derivatives
|
||||||||||||||||||||||
net
of tax of $8
|
-
|
-
|
-
|
-
|
-
|
-
|
5
|
|||||||||||||||
Total
comprehensive loss
|
-
|
-
|
-
|
-
|
-
|
(979
|
)
|
152
|
||||||||||||||
Balance
at December 31, 2004
|
$
|
1,146
|
$
|
277
|
$
|
2,335
|
$
|
(477
|
)
|
$
|
(74
|
)
|
$
|
871
|
$
|
(146
|
)
|
|||||
Cash
dividends paid
|
-
|
-
|
-
|
-
|
-
|
(254
|
)
|
-
|
||||||||||||||
Stock-based
compensation and
|
||||||||||||||||||||||
employee
stock purchase, net
|
22
|
280
|
-
|
115
|
(24
|
)
|
-
|
-
|
||||||||||||||
Treasury
stock purchased
|
-
|
-
|
-
|
(12
|
)
|
-
|
-
|
-
|
||||||||||||||
Tax
benefit from exercise of options
|
||||||||||||||||||||||
and
restricted stock
|
-
|
75
|
-
|
-
|
-
|
-
|
-
|
|||||||||||||||
Total
dividends and other transactions
|
||||||||||||||||||||||
with
shareholders
|
22
|
355
|
-
|
103
|
(24
|
)
|
(254
|
)
|
-
|
|||||||||||||
Asbestos
trust shares
|
149
|
2,186
|
(2,335
|
)
|
-
|
-
|
-
|
-
|
||||||||||||||
Comprehensive
income (loss):
|
||||||||||||||||||||||
Net
income
|
-
|
-
|
-
|
-
|
-
|
2,358
|
-
|
|||||||||||||||
Other
comprehensive income:
|
||||||||||||||||||||||
Cumulative
translation
|
||||||||||||||||||||||
adjustment
|
-
|
-
|
-
|
-
|
-
|
-
|
(48
|
)
|
||||||||||||||
Realization
of losses included in
|
||||||||||||||||||||||
net
income
|
-
|
-
|
-
|
-
|
-
|
-
|
7
|
|||||||||||||||
Minimum
pension liability
|
||||||||||||||||||||||
adjustment,
net of tax benefit
|
||||||||||||||||||||||
of
$23
|
-
|
-
|
-
|
-
|
-
|
-
|
(54
|
)
|
||||||||||||||
Net
unrealized losses on
|
||||||||||||||||||||||
investments
and derivatives,
|
||||||||||||||||||||||
net
of tax benefit of $15
|
-
|
-
|
-
|
-
|
-
|
-
|
(25
|
)
|
||||||||||||||
Total
comprehensive income
|
-
|
-
|
-
|
-
|
-
|
2,358
|
(120
|
)
|
||||||||||||||
Balance
at December 31, 2005
|
$
|
1,317
|
$
|
2,818
|
$
|
-
|
$
|
(374
|
)
|
$
|
(98
|
)
|
$
|
2,975
|
$
|
(266
|
)
|
Accumulated
other comprehensive income
|
December
31
|
|||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Cumulative
translation adjustment
|
$
|
(72
|
)
|
$
|
(31
|
)
|
$
|
(63
|
)
|
|
Pension
liability adjustments
|
(184
|
)
|
(130
|
)
|
(245
|
)
|
||||
Unrealized
gains (losses) on investments and
|
||||||||||
derivatives
|
(10
|
)
|
15
|
10
|
||||||
Total
accumulated other comprehensive income
|
$
|
(266
|
)
|
$
|
(146
|
)
|
$
|
(298
|
)
|
|
Shares
of common stock
|
December
31
|
|||||||||
Millions
of shares
|
2005
|
2004
|
2003
|
|||||||
Issued
|
527
|
458
|
457
|
|||||||
In
treasury
|
(13
|
)
|
(16
|
)
|
(18
|
)
|
||||
Total
shares of common stock outstanding
|
514
|
442
|
439
|
-
|
stock
options, including incentive stock options and nonqualified stock
options;
|
-
|
stock
appreciation rights, in tandem with stock options or
freestanding;
|
-
|
restricted
stock;
|
-
|
performance
share awards; and
|
-
|
stock
value equivalent awards.
|
Weighted
|
||||||||||
Number
of Shares
|
Exercise
Price
|
Average
Exercise
Price
|
||||||||
Stock
Options
|
(in
millions)
|
per
Share
|
per
Share
|
|||||||
Outstanding
at December 31, 2002
|
18.5
|
$
|
9.10
- 61.50
|
$
|
32.10
|
|||||
Granted
|
2.4
|
18.60
- 24.76
|
23.45
|
|||||||
Exercised
|
(0.4
|
)
|
8.28
- 23.52
|
14.75
|
||||||
Forfeited
|
(1.0
|
)
|
9.10
- 54.50
|
32.07
|
||||||
Outstanding
at December 31. 2003
|
19.5
|
$
|
9.10
- 61.50
|
$
|
31.34
|
|||||
Granted
|
2.2
|
26.03
- 40.18
|
29.22
|
|||||||
Exercised
|
(1.5
|
)
|
9.10
- 39.55
|
21.87
|
||||||
Forfeited
|
(0.8
|
)
|
9.10
- 54.50
|
33.19
|
||||||
Outstanding
at December 31, 2004
|
19.4
|
$
|
9.10
- 61.50
|
$
|
31.74
|
|||||
Granted
|
1.4
|
40.94
- 68.92
|
49.44
|
|||||||
Exercised
|
(9.1
|
)
|
9.10
- 61.50
|
32.09
|
||||||
Forfeited
|
(0.5
|
)
|
9.10
- 62.71
|
33.02
|
||||||
Outstanding
at December 31, 2005
|
11.2
|
$
|
9.10
- 68.92
|
$
|
33.61
|
Outstanding
|
|||||||||||||||||||
Weighted
|
Exercisable
|
||||||||||||||||||
Average
|
Weighted
|
Weighted
|
|||||||||||||||||
Number
of
|
Remaining
|
Average
|
Number
of
|
Average
|
|||||||||||||||
Range
of
|
Shares
|
Contractual
|
Exercise
|
Shares
|
Exercise
|
||||||||||||||
Exercise
Prices
|
(in
millions)
|
Life
|
Price
|
(in
millions)
|
Price
|
||||||||||||||
$
|
9.10
- 23.79
|
2.5
|
6.5
|
$
|
18.65
|
1.7
|
$
|
17.25
|
|||||||||||
$
|
23.80
- 32.40
|
3.5
|
5.9
|
28.78
|
1.9
|
28.90
|
|||||||||||||
$
|
32.41
- 40.93
|
2.8
|
4.4
|
38.76
|
2.7
|
38.76
|
|||||||||||||
$
|
40.94
- 68.92
|
2.4
|
6.8
|
50.61
|
1.0
|
52.10
|
|||||||||||||
$
|
9.10
- 68.92
|
11.2
|
5.9
|
$
|
33.61
|
7.3
|
$
|
32.92
|
Millions
of shares
|
2005
|
2004
|
2003
|
|||||||
Basic
weighted average common shares outstanding
|
505
|
437
|
434
|
|||||||
Dilutive
effect of:
|
||||||||||
Stock
options
|
5
|
2
|
2
|
|||||||
Convertible
senior notes premium
|
8
|
-
|
-
|
|||||||
Restricted
stock
|
1
|
1
|
-
|
|||||||
Other
|
-
|
1
|
1
|
|||||||
Diluted
weighted average common shares outstanding
|
519
|
441
|
437
|
-
|
our
defined contribution plans provide retirement benefits in return
for
services rendered. These plans provide an individual account for
each
participant and have terms that specify how contributions to the
participant’s account are to be determined rather than the amount of
pension benefits the participant is to receive. Contributions to
these
plans are based on pretax income and/or discretionary amounts determined
on an annual basis. Our expense for the defined contribution plans
for
both continuing and discontinued operations totaled $164 million
in 2005,
$147 million in 2004, and $87 million in 2003. Additionally, we
participate in a Canadian multi-employer plan to which we contributed
$24
million and $20 million in 2005 and 2004, respectively. For 2004,
we
amended certain defined contribution plans to allow for a non-elective
contribution, which resulted in an increase of $53 million over the
2003
expense;
|
-
|
our
defined benefit plans include both funded and unfunded pension plans,
which define an amount of pension benefit to be provided, usually
as a
function of age, years of service, or compensation;
and
|
-
|
our
postretirement medical plans are offered to specific eligible employees.
These plans are contributory. For some plans, our liability is limited
to
a fixed contribution amount for each participant or dependent. The
plan
participants share the total cost for all benefits provided above
our
fixed contributions. Participants’ contributions are adjusted as required
to cover benefit payments. We have made no commitment to adjust the
amount
of our contributions; therefore, the computed accumulated postretirement
benefit obligation amount is not affected by the expected future
health
care cost inflation rate.
|
Pension
Benefits
|
Other
|
||||||||||||||||||
United
|
United
|
Postretirement
|
|||||||||||||||||
Benefit
obligation
|
States
|
Int’l
|
States
|
Int’l
|
Benefits
|
||||||||||||||
Millions
of dollars
|
2005
|
2004
|
2005
|
2004
|
|||||||||||||||
Change
in benefit obligation
|
|||||||||||||||||||
Benefit
obligation at beginning of period
|
$
|
166
|
$
|
3,127
|
$
|
160
|
$
|
2,501
|
$
|
175
|
$
|
188
|
|||||||
Service
cost
|
1
|
72
|
1
|
92
|
1
|
1
|
|||||||||||||
Interest
cost
|
9
|
172
|
10
|
155
|
10
|
11
|
|||||||||||||
Plan
participants’ contributions
|
-
|
16
|
-
|
22
|
9
|
12
|
|||||||||||||
Effect
of business combinations and new plans
|
-
|
1
|
-
|
14
|
-
|
-
|
|||||||||||||
Amendments
|
-
|
-
|
-
|
(1
|
)
|
-
|
-
|
||||||||||||
Settlements/curtailments
|
-
|
(69
|
)
|
-
|
(9
|
)
|
-
|
-
|
|||||||||||
Currency
fluctuations
|
-
|
(41
|
)
|
-
|
371
|
-
|
-
|
||||||||||||
Actuarial
(gain) loss
|
8
|
416
|
8
|
72
|
(19
|
)
|
(16
|
)
|
|||||||||||
Benefits
paid
|
(11
|
)
|
(94
|
)
|
(13
|
)
|
(90
|
)
|
(17
|
)
|
(21
|
)
|
|||||||
Benefit
obligation at end of period
|
$
|
173
|
$
|
3,600
|
$
|
166
|
$
|
3,127
|
$
|
159
|
$
|
175
|
|||||||
Accumulated
benefit obligation at end of period
|
$
|
172
|
$
|
3,014
|
$
|
165
|
$
|
2,451
|
$
|
-
|
$
|
-
|
Pension
Benefits
|
Other
|
||||||||||||||||||
United
|
United
|
Postretirement
|
|||||||||||||||||
Plan
assets
|
States
|
Int’l
|
States
|
Int’l
|
Benefits
|
||||||||||||||
Millions
of dollars
|
2005
|
2004
|
2005
|
2004
|
|||||||||||||||
Change
in plan assets
|
|||||||||||||||||||
Fair value of plan assets at beginning of | |||||||||||||||||||
period
|
$
|
125
|
$
|
2,576
|
$
|
113
|
$
|
2,003
|
$
|
-
|
$
|
-
|
|||||||
Actual
return on plan assets
|
12
|
541
|
17
|
259
|
-
|
-
|
|||||||||||||
Employer
contributions
|
7
|
74
|
8
|
77
|
8
|
9
|
|||||||||||||
Settlements
and transfers
|
-
|
(1
|
)
|
-
|
(8
|
)
|
-
|
-
|
|||||||||||
Plan
participants’ contributions
|
-
|
16
|
-
|
22
|
9
|
12
|
|||||||||||||
Effect of business combinations and new | |||||||||||||||||||
plans
|
-
|
-
|
-
|
9
|
-
|
-
|
|||||||||||||
Currency
fluctuations
|
-
|
(35
|
)
|
-
|
304
|
-
|
-
|
||||||||||||
Benefits
paid
|
(11
|
)
|
(94
|
)
|
(13
|
)
|
(90
|
)
|
(17
|
)
|
(21
|
)
|
|||||||
Fair
value of plan assets at end of period
|
$
|
133
|
$
|
3,077
|
$
|
125
|
$
|
2,576
|
$
|
-
|
$
|
-
|
|
Percentage
of Plan Assets at Year-End
|
|||||||||||||||
Target
Allocation
|
United
States
|
Int’l
|
United
States
|
Int’l
|
||||||||||||
2006
|
2005
|
2004
|
||||||||||||||
Asset
category
|
||||||||||||||||
Equity
securities
|
55%
- 70
|
%
|
63
|
%
|
62
|
%
|
63
|
%
|
64
|
%
|
||||||
Debt
securities
|
25%
- 45
|
%
|
36
|
%
|
30
|
%
|
33
|
%
|
34
|
%
|
||||||
Real
estate
|
0
|
%
|
0
|
%
|
0
|
%
|
0
|
%
|
0
|
%
|
||||||
Other
|
0%
- 10
|
%
|
1
|
%
|
8
|
%
|
4
|
%
|
2
|
%
|
||||||
Total
|
100
|
%
|
100
|
%
|
100
|
%
|
100
|
%
|
100
|
%
|
Pension
Benefits
|
Other
|
||||||||||||||||||
United
|
United
|
Postretirement
|
|||||||||||||||||
States
|
Int’l
|
States
|
Int’l
|
Benefits
|
|||||||||||||||
Millions
of dollars
|
2005
|
2004
|
2005
|
2004
|
|||||||||||||||
Fair
value of plan assets at end of period
|
$
|
133
|
$
|
3,077
|
$
|
125
|
$
|
2,576
|
$
|
-
|
$
|
-
|
|||||||
Benefit
obligation at end of period
|
173
|
3,600
|
166
|
3,127
|
159
|
175
|
|||||||||||||
Funded
status
|
$
|
(40
|
)
|
$
|
(523
|
)
|
$
|
(41
|
)
|
$
|
(551
|
)
|
$
|
(159
|
)
|
$
|
(175
|
)
|
|
Employer
contribution
|
-
|
21
|
-
|
19
|
1
|
1
|
|||||||||||||
Unrecognized
transition asset
|
(1
|
)
|
-
|
(1
|
)
|
-
|
-
|
-
|
|||||||||||
Unrecognized
actuarial loss (gain)
|
76
|
602
|
74
|
632
|
(7
|
)
|
12
|
||||||||||||
Unrecognized
prior service benefit
|
-
|
(8
|
)
|
-
|
(3
|
)
|
(3
|
)
|
(4
|
)
|
|||||||||
Purchase
accounting adjustment
|
-
|
(78
|
)
|
-
|
(82
|
)
|
-
|
-
|
|||||||||||
Net
amount recognized
|
$
|
35
|
$
|
14
|
$
|
32
|
$
|
15
|
$
|
(168
|
)
|
$
|
(166
|
)
|
Pension
Benefits
|
Other
|
||||||||||||||||||
United
|
United
|
Postretirement
|
|||||||||||||||||
States
|
Int’l
|
States
|
Int’l
|
Benefits
|
|||||||||||||||
Millions
of dollars
|
2005
|
2004
|
2005
|
2004
|
|||||||||||||||
Prepaid
benefit cost
|
$
|
37
|
$
|
115
|
$
|
34
|
$
|
103
|
$
|
-
|
$
|
-
|
|||||||
Accrued
benefit liability, including additional
|
|||||||||||||||||||
minimum
liability
|
(77
|
)
|
(295
|
)
|
(74
|
)
|
(214
|
)
|
(168
|
)
|
(166
|
)
|
|||||||
Intangible
asset
|
-
|
2
|
-
|
8
|
-
|
-
|
|||||||||||||
Accumulated
other comprehensive income,
|
|||||||||||||||||||
net
of tax
|
49
|
135
|
47
|
83
|
-
|
-
|
|||||||||||||
Deferred
tax asset
|
26
|
57
|
25
|
35
|
-
|
-
|
|||||||||||||
Net
amount recognized
|
$
|
35
|
$
|
14
|
$
|
32
|
$
|
15
|
$
|
(168
|
)
|
$
|
(166
|
)
|
Pension
Benefits
|
|||||||
Millions
of dollars
|
2005
|
2004
|
|||||
Projected
benefit obligation
|
$
|
2,170
|
$
|
1,942
|
|||
Accumulated
benefit obligation
|
$
|
1,952
|
$
|
1,629
|
|||
Fair
value of plan assets
|
$
|
1,756
|
$
|
1,503
|
Pension
Benefits
|
Other
|
|||||||||
United
|
Postretirement
|
|||||||||
Millions
of dollars
|
States
|
Int’l
|
Benefits
|
|||||||
2006
|
$
|
13
|
$
|
96
|
$
|
14
|
||||
2007
|
11
|
99
|
15
|
|||||||
2008
|
11
|
105
|
15
|
|||||||
2009
|
11
|
107
|
15
|
|||||||
2010
|
11
|
111
|
15
|
|||||||
Years
2011 - 2015
|
58
|
380
|
72
|
Pension
Benefits
|
Other
|
|||||||||||||||||||||||||||
United
|
United
|
United
|
Postretirement
|
|||||||||||||||||||||||||
States
|
Int’l
|
States
|
Int’l
|
States
|
Int’l
|
Benefits
|
||||||||||||||||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
2005
|
2004
|
2003
|
||||||||||||||||||||||
Components
of net
|
||||||||||||||||||||||||||||
periodic
benefit cost
|
||||||||||||||||||||||||||||
Service
cost
|
$
|
1
|
$
|
72
|
$
|
1
|
$
|
92
|
$
|
1
|
$
|
72
|
$
|
1
|
$
|
1
|
$
|
1
|
||||||||||
Interest
cost
|
9
|
172
|
10
|
155
|
10
|
120
|
10
|
11
|
12
|
|||||||||||||||||||
Expected
return on plan
|
||||||||||||||||||||||||||||
assets
|
(10
|
)
|
(186
|
)
|
(11
|
)
|
(173
|
)
|
(12
|
)
|
(136
|
)
|
-
|
-
|
-
|
|||||||||||||
Transition
amount
|
-
|
-
|
-
|
(1
|
)
|
-
|
(1
|
)
|
-
|
-
|
-
|
|||||||||||||||||
Amortization
of prior service
|
||||||||||||||||||||||||||||
cost
|
-
|
-
|
-
|
-
|
-
|
-
|
(1
|
)
|
(1
|
)
|
-
|
|||||||||||||||||
Settlements/curtailments
|
-
|
5
|
1
|
(2
|
)
|
2
|
-
|
-
|
-
|
-
|
||||||||||||||||||
Recognized
actuarial loss
|
4
|
17
|
3
|
16
|
1
|
18
|
-
|
1
|
1
|
|||||||||||||||||||
Net
periodic benefit cost
|
$
|
4
|
$
|
80
|
$
|
4
|
$
|
87
|
$
|
2
|
$
|
73
|
$
|
10
|
$
|
12
|
$
|
14
|
Weighted-average
|
||||||||||||||||||||||||||||
assumptions
used to
|
Pension
Benefits
|
|||||||||||||||||||||||||||
determine
benefit
|
United
|
United
|
United
|
Other
Postretirement
|
||||||||||||||||||||||||
obligations
at
|
States
|
Int’l
|
States
|
Int’l
|
States
|
Int’l
|
Benefits
|
|||||||||||||||||||||
measurement
date
|
2005
|
2004
|
2003
|
2005
|
2004
|
2003
|
||||||||||||||||||||||
Discount
rate
|
5.75
|
%
|
2.25-8.0
|
%
|
5.75
|
%
|
2.5-8.0
|
%
|
6.25
|
%
|
2.5-9.0
|
%
|
5.75
|
%
|
5.75
|
%
|
6.25
|
%
|
||||||||||
Rate
of compensation
|
||||||||||||||||||||||||||||
increase
|
4.5
|
%
|
2.0-5.0
|
%
|
4.5
|
%
|
2.0-5.0
|
%
|
4.5
|
%
|
2.0-6.5
|
%
|
N/A
|
N/A
|
N/A
|
Weighted-average
|
||||||||||||||||||||||||||||
assumptions
used to
|
||||||||||||||||||||||||||||
determine
net
|
Pension
Benefits
|
|||||||||||||||||||||||||||
periodic
benefit cost
|
United
|
United
|
United
|
Other
Postretirement
|
||||||||||||||||||||||||
for
years ended
|
States
|
Int’l
|
States
|
Int’l
|
States
|
Int’l
|
Benefits
|
|||||||||||||||||||||
December
31
|
2005
|
2004
|
2003
|
2005
|
2004
|
2003
|
||||||||||||||||||||||
Discount
rate
|
5.75
|
%
|
2.5-8.0
|
%
|
6.25
|
%
|
2.5-9.0
|
%
|
7.0
|
%
|
2.5-7.5
|
%
|
5.75
|
%
|
6.25
|
%
|
7.0
|
%
|
||||||||||
Expected
return on plan assets
|
8.5
|
%
|
5.0-7.0
|
%
|
8.5
|
%
|
5.25-7.5
|
%
|
8.75
|
%
|
5.5-8.0
|
%
|
N/A
|
N/A
|
N/A
|
|||||||||||||
Rate
of compensation
|
||||||||||||||||||||||||||||
increase
|
4.5
|
%
|
2.0-5.0
|
%
|
4.5
|
%
|
2.0-6.5
|
%
|
4.5
|
%
|
2.0-7.0
|
%
|
N/A
|
N/A
|
N/A
|
Assumed
health care cost trend rates at
|
||||||||||
December
31
|
2005
|
2004
|
2003
|
|||||||
Health
care cost trend rate assumed for next year
|
10.0
|
%
|
11.5
|
%
|
13.0
|
%
|
||||
Rate
to which the cost trend rate is assumed to
|
||||||||||
decline
(the ultimate trend rate)
|
5.0
|
%
|
5.0
|
%
|
5.0
|
%
|
||||
Year
that the rate reached the ultimate trend rate
|
2008
|
2008
|
2008
|
One-Percentage-Point
|
|||||||
Millions
of dollars
|
Increase
|
(Decrease)
|
|||||
Effect
on total of service and interest cost components
|
$
|
-
|
$
|
-
|
|||
Effect
on the postretirement benefit obligation
|
$
|
8
|
$
|
(7
|
)
|
Combined
operating results
|
Years
ended December 31
|
|||||||||
Millions
of dollars
|
2005
|
2004
|
2003
|
|||||||
Revenue
|
$
|
3,626
|
$
|
3,887
|
$
|
3,708
|
||||
Operating
income (loss)
|
$
|
(25
|
)
|
$
|
7
|
$
|
201
|
|||
Net
income (loss)
|
$
|
(7
|
)
|
$
|
(12
|
)
|
$
|
175
|
Combined
financial position
|
December
31
|
||||||
Millions
of dollars
|
2005
|
2004
|
|||||
Current
assets
|
$
|
2,421
|
$
|
2,339
|
|||
Noncurrent
assets
|
2,760
|
2,723
|
|||||
Total
|
$
|
5,181
|
$
|
5,062
|
|||
Current
liabilities
|
$
|
2,226
|
$
|
1,950
|
|||
Noncurrent
liabilities
|
2,400
|
2,394
|
|||||
Shareholders’
equity
|
555
|
718
|
|||||
Total
|
$
|
5,181
|
$
|
5,062
|
-
|
during
the second quarter of 2001, we formed a joint venture, WellDynamics,
with
Shell in which we held a 50% equity interest and accounted for the
investment using the equity method in our Digital and Consulting
Solutions
segment. The joint venture was established for the further development
and
deployment of new technologies related to completions and well
intervention services and products. In the first quarter of 2004,
Halliburton and Shell restructured WellDynamics whereby Halliburton
acquired an additional 1% of WellDynamics from Shell, giving Halliburton
51% ownership and control of day-to-day operations. The joint venture
is
considered a variable interest entity under FIN 46, and we have determined
that we are the primary beneficiary of the entity. Beginning in the
first
quarter of 2004, WellDynamics was consolidated. The consolidation
of
WellDynamics resulted in an increase to our goodwill of $109 million,
which was previously carried as equity method goodwill in our investment
balance, and an increase in long-term debt of $27 million. There
are no
assets of WellDynamics that collateralize its
obligations;
|
-
|
during
2001, we formed a joint venture that owns and operates heavy equipment
transport vehicles in the United Kingdom and in which we own a 50%
equity
interest with an unrelated partner. This variable interest entity
was
formed to construct, operate, and service certain assets for a third
party
and was funded with third-party debt. The construction of the assets
was
completed in the second quarter of 2004, and the operating and service
contract related to the assets extends through 2023. The proceeds
from the
debt financing were used to construct the assets and will be paid
down
with cash flows generated during the operation and service phase
of the
contract with the third party. As of December 31, 2005, the joint
venture
had total assets of $147 million and total liabilities of $152 million.
Our aggregate exposure to loss as a result of our involvement with
this
joint venture is limited to our equity investment and subordinated
debt of
$7 million and any future losses related to the operation of the
assets.
We are not the primary beneficiary. The joint venture is accounted
for
under the equity method of
accounting;
|
-
|
we
are involved in three privately funded initiatives executed through
joint
ventures to design, build, operate, and maintain roadways for certain
government agencies in the United Kingdom. We have a 25% ownership
interest in these joint ventures and account for them under the equity
method. The joint ventures have obtained financing through third
parties
that is not guaranteed by us. These joint ventures are considered
variable
interest entities. We are not the primary beneficiary of these joint
ventures and, therefore, account for them using the equity method.
As of
December 31, 2005, these joint ventures had total assets of $1.4
billion
and total liabilities of $1.5 billion. Our maximum exposure to loss
is
limited to our equity investments in and loans to the joint ventures,
which totaled $35 million at December 31,
2005;
|
-
|
we
participate in a privately funded initiative executed through an
unincorporated joint venture and operating company formed for operating
and maintaining a railroad freight business in Australia. We own
36.7% of
the joint venture and operating company and we are accounting for
these
investments using the equity method. This joint venture is considered
a
variable interest entity. The joint venture is funded through senior
and
subordinated debt and equity contributions from the joint venture
partners. We are not the primary beneficiary of the joint venture.
As of
December 31, 2005, the joint venture had total assets of $796 million
and
total liabilities of $672 million. Our maximum exposure to loss is
limited
to our equity investments and senior operating notes in the joint
venture
and the operating company totaling $81 million and our commit to
fund an
additional $9 million of notes to the operating company as of December
31,
2005; and
|
-
|
we
participate in a privately funded initiative executed through certain
joint ventures formed to design, build, operate, and maintain a viaduct
and several bridges in southern Ireland. The joint ventures were
funded
through debt and were formed with very little equity. We have up
to a 25%
ownership interest in the project’s joint ventures, and we are accounting
for this interest under the equity method. These joint ventures are
considered variable interest entities. We are not the primary beneficiary
of the joint ventures. As of December 31, 2005, the joint ventures
had
total assets of $239 million and total liabilities of $226 million.
Our
maximum exposure to loss is limited to our equity investments in
and loan
to the joint venture, totaling $4 million at December 31, 2005, and
our
share of any future losses resulting from the
project.
|
-
|
during
2005, we formed a joint venture to engineer and construct a gas
monetization facility. We own a 50% equity interest and determined
that we
are the primary beneficiary of the joint venture. The joint venture
is
consolidated. At December 31, 2005, the joint venture’s had $324 million
in total assets and $311 million in total liabilities. There are
no
consolidated assets that collateralize the joint venture obligations,
however at December 31, 2005, the joint venture had approximately
$173
million of cash which relates to advance billings in connection with
the
joint venture’s obligations under the EPC contract;
and
|
-
|
we
also have equity ownership in three joint ventures to execute EPC
projects. Our equity ownership ranges from 33% to 50%, and these
joint
ventures are considered variable interest entities. We are not the
primary
beneficiary, and we account for these joint ventures under the equity
method. At December 31, 2005, these joint ventures had aggregate
assets of
$861 million and aggregate liabilities of $912
million.
|
Millions
of dollars and shares
|
Years
ended December 31
|
|||||||||||||||
except
per share and employee data
|
2005
|
2004
|
2003
|
2002
|
2001
|
|||||||||||
Total
revenue
|
$
|
20,994
|
$
|
20,466
|
$
|
16,271
|
$
|
12,572
|
$
|
13,046
|
||||||
Total
operating income (loss)
|
$
|
2,662
|
$
|
837
|
$
|
720
|
$
|
(112
|
)
|
$
|
1,084
|
|||||
Nonoperating
expense, net
|
(170
|
)
|
(186
|
)
|
(108
|
)
|
(116
|
)
|
(130
|
)
|
||||||
Income
(loss) from continuing
|
||||||||||||||||
operations
before income taxes
|
||||||||||||||||
and
minority interest
|
2,492
|
651
|
612
|
(228
|
)
|
954
|
||||||||||
Provision
for income taxes
|
(79
|
)
|
(241
|
)
|
(234
|
)
|
(80
|
)
|
(384
|
)
|
||||||
Minority
interest in net income of
|
||||||||||||||||
consolidated
subsidiaries
|
(56
|
)
|
(25
|
)
|
(39
|
)
|
(38
|
)
|
(19
|
)
|
||||||
Income
(loss) from continuing operations
|
$
|
2,357
|
$
|
385
|
$
|
339
|
$
|
(346
|
)
|
$
|
551
|
|||||
Income
(loss) from discontinued operations
|
$
|
1
|
$
|
(1,364
|
)
|
$
|
(1,151
|
)
|
$
|
(652
|
)
|
$
|
257
|
|||
Net
income (loss)
|
$
|
2,358
|
$
|
(979
|
)
|
$
|
(820
|
)
|
$
|
(998
|
)
|
$
|
809
|
|||
Basic
income (loss) per share:
|
||||||||||||||||
Continuing
operations
|
$
|
4.67
|
$
|
0.88
|
$
|
0.78
|
$
|
(0.80
|
)
|
$
|
1.29
|
|||||
Net
income (loss)
|
4.67
|
(2.25
|
)
|
(1.89
|
)
|
(2.31
|
)
|
1.89
|
||||||||
Diluted
income (loss) per share:
|
||||||||||||||||
Continuing
operations
|
4.54
|
0.87
|
0.78
|
(0.80
|
)
|
1.28
|
||||||||||
Net
income (loss)
|
4.54
|
(2.22
|
)
|
(1.88
|
)
|
(2.31
|
)
|
1.88
|
||||||||
Cash
dividends per share
|
0.50
|
0.50
|
0.50
|
0.50
|
0.50
|
|||||||||||
Return
on average shareholders’ equity
|
45.76
|
%
|
(30.22
|
)%
|
(26.86
|
)%
|
(24.02
|
)%
|
18.64
|
%
|
||||||
Financial
position:
|
||||||||||||||||
Net
working capital
|
$
|
4,890
|
$
|
2,898
|
$
|
1,355
|
$
|
2,288
|
$
|
2,665
|
||||||
Total
assets
|
15,010
|
15,864
|
15,556
|
12,844
|
10,966
|
|||||||||||
Property,
plant, and equipment, net
|
2,648
|
2,553
|
2,526
|
2,629
|
2,669
|
|||||||||||
Long-term
debt (including current maturities)
|
3,174
|
3,940
|
3,437
|
1,476
|
1,484
|
|||||||||||
Shareholders’
equity
|
6,372
|
3,932
|
2,547
|
3,558
|
4,752
|
|||||||||||
Total
capitalization
|
9,568
|
7,887
|
6,002
|
5,083
|
6,280
|
|||||||||||
Shareholders’
equity per share
|
12.40
|
8.90
|
5.80
|
8.16
|
10.95
|
|||||||||||
Basic
weighted average common shares
|
||||||||||||||||
outstanding
|
505
|
437
|
434
|
432
|
428
|
|||||||||||
Diluted
weighted average common shares
|
||||||||||||||||
outstanding
|
519
|
441
|
437
|
432
|
430
|
|||||||||||
Other
financial data:
|
||||||||||||||||
Capital
expenditures
|
$
|
(651
|
)
|
$
|
(575
|
)
|
$
|
(515
|
)
|
$
|
(764
|
)
|
$
|
(797
|
)
|
|
Long-term
borrowings (repayments), net
|
(799
|
)
|
476
|
1,896
|
(15
|
)
|
412
|
|||||||||
Depreciation,
depletion, and
|
||||||||||||||||
amortization
expense
|
504
|
509
|
518
|
505
|
531
|
|||||||||||
Goodwill
amortization included in
|
||||||||||||||||
depreciation,
depletion, and
|
||||||||||||||||
amortization
expense
|
-
|
-
|
-
|
-
|
42
|
|||||||||||
Payroll
and employee benefits
|
(5,888
|
)
|
(5,608
|
)
|
(5,154
|
)
|
(4,875
|
)
|
(4,818
|
)
|
||||||
Number
of employees
|
106,000
|
97,000
|
101,000
|
83,000
|
85,000
|
Millions
of dollars except per
|
Quarter
|
|||||||||||||||
share
data
|
First
|
Second
|
Third
|
Fourth
|
Year
|
|||||||||||
2005
|
||||||||||||||||
Revenue
|
$
|
4,938
|
$
|
5,163
|
$
|
5,095
|
$
|
5,798
|
$
|
20,994
|
||||||
Operating
income
|
586
|
607
|
690
|
779
|
2,662
|
|||||||||||
Income
from continuing operations
|
367
|
391
|
499
|
1,100
|
2,357
|
|||||||||||
Income
(loss) from discontinued operations
|
(2
|
)
|
1
|
-
|
2
|
1
|
||||||||||
Net
income
|
365
|
392
|
499
|
1,102
|
2,358
|
|||||||||||
Earnings
per share:
|
||||||||||||||||
Basic
income per share:
|
||||||||||||||||
Income
from continuing operations
|
0.73
|
0.78
|
0.99
|
2.16
|
4.67
|
|||||||||||
Income
(loss) from discontinued
|
||||||||||||||||
operations
|
-
|
-
|
-
|
-
|
-
|
|||||||||||
Net
income
|
0.73
|
0.78
|
0.99
|
2.16
|
4.67
|
|||||||||||
Diluted
income per share:
|
||||||||||||||||
Income
from continuing operations
|
0.72
|
0.76
|
0.95
|
2.08
|
4.54
|
|||||||||||
Income
(loss) from discontinued
|
||||||||||||||||
operations
|
-
|
-
|
-
|
-
|
-
|
|||||||||||
Net
income
|
0.72
|
0.76
|
0.95
|
2.08
|
4.54
|
|||||||||||
Cash
dividends paid per share
|
0.125
|
0.125
|
0.125
|
0.125
|
0.50
|
|||||||||||
Common
stock prices (1)
|
||||||||||||||||
High
|
45.29
|
49.39
|
69.78
|
69.37
|
69.78
|
|||||||||||
Low
|
37.18
|
39.65
|
45.76
|
54.70
|
37.18
|
|||||||||||
2004
|
||||||||||||||||
Revenue
|
$
|
5,519
|
$
|
4,956
|
$
|
4,790
|
$
|
5,201
|
$
|
20,466
|
||||||
Operating
income (loss)
|
175
|
(26
|
)
|
342
|
346
|
837
|
||||||||||
Income
(loss) from continuing operations
|
76
|
(58
|
)
|
186
|
181
|
385
|
||||||||||
Loss
from discontinued operations
|
(141
|
)
|
(609
|
)
|
(230
|
)
|
(384
|
)
|
(1,364
|
)
|
||||||
Net
loss
|
(65
|
)
|
(667
|
)
|
(44
|
)
|
(203
|
)
|
(979
|
)
|
||||||
Earnings
per share:
|
||||||||||||||||
Basic
income (loss) per share:
|
||||||||||||||||
Income
(loss) from continuing operations
|
0.17
|
(0.13
|
)
|
0.43
|
0.41
|
0.88
|
||||||||||
Loss
from discontinued operations
|
(0.32
|
)
|
(1.39
|
)
|
(0.54
|
)
|
(0.88
|
)
|
(3.13
|
)
|
||||||
Net
loss
|
(0.15
|
)
|
(1.52
|
)
|
(0.11
|
)
|
(0.47
|
)
|
(2.25
|
)
|
||||||
Diluted
income (loss) per share:
|
||||||||||||||||
Income
(loss) from continuing operations
|
0.17
|
(0.13
|
)
|
0.42
|
0.40
|
0.87
|
||||||||||
Loss
from discontinued operations
|
(0.32
|
)
|
(1.39
|
)
|
(0.51
|
)
|
(0.86
|
)
|
(3.09
|
)
|
||||||
Net
loss
|
(0.15
|
)
|
(1.52
|
)
|
(0.09
|
)
|
(0.46
|
)
|
(2.22
|
)
|
||||||
Cash
dividends paid per share
|
0.125
|
0.125
|
0.125
|
0.125
|
0.50
|
|||||||||||
Common
stock prices (1)
|
||||||||||||||||
High
|
32.70
|
32.35
|
33.98
|
41.69
|
41.69
|
|||||||||||
Low
|
25.80
|
27.35
|
26.45
|
33.08
|
25.80
|
2.
|
Financial
Statement Schedules:
|
Page
No.
|
Report
on supplemental schedule of KPMG LLP
|
124
|
|
Schedule
II - Valuation and qualifying accounts for the three
|
||
years
ended December 31, 2005
|
125
|
|
Note:
All schedules not filed with this report required by
|
||
Regulation
S-X have been omitted as not applicable or not
|
||
required,
or the information required has been included in the
|
||
notes
to financial statements.
|
Additions
|
||||||||||||||||
Balance
at
|
Charged
to
|
Charged
to
|
Balance
at
|
|||||||||||||
Beginning
|
Costs
and
|
Other
|
End
of
|
|||||||||||||
Descriptions
|
of
Period
|
Expenses
|
Accounts
|
Deductions
|
Period
|
|||||||||||
Year
ended December 31, 2003:
|
||||||||||||||||
Deducted
from accounts and notes receivable:
|
||||||||||||||||
Allowance
for bad debts
|
$
|
157
|
$
|
44
|
$
|
4
|
$
|
(30)
(a
|
)
|
$
|
175
|
|||||
Accrued
reorganization charges
|
$
|
10
|
$
|
-
|
$
|
-
|
$
|
(9
|
)
|
$
|
1
|
|||||
Reserve
for disputed and unallowable costs
|
||||||||||||||||
incurred
under government contracts
|
$
|
13
|
$
|
-
|
$
|
36
(b
|
)
|
$
|
(1
|
) |
$
|
48
|
||||
Year
ended December 31, 2004:
|
||||||||||||||||
Deducted
from accounts and notes receivable:
|
||||||||||||||||
Allowance
for bad debts
|
$
|
175
|
$
|
22
|
$
|
2
|
$
|
(72)
(a
|
)
|
$
|
127
|
|||||
Accrued
reorganization charges
|
$
|
1
|
$
|
40
|
$
|
-
|
$
|
(22
|
)
|
$
|
19
|
|||||
Reserve
for disputed and unallowable costs
|
||||||||||||||||
incurred
under government contracts
|
$
|
48
|
$
|
-
|
$
|
83
(b
|
)
|
$
|
-
|
$
|
131
|
|||||
Year
ended December 31, 2005:
|
||||||||||||||||
Deducted
from accounts and notes receivable:
|
||||||||||||||||
Allowance
for bad debts
|
$
|
127
|
$
|
64
|
$
|
-
|
$
|
(101)
(a
|
)
|
$
|
90
|
|||||
Accrued
reorganization charges
|
$
|
19
|
$
|
-
|
$
|
-
|
$
|
(19
|
)
|
$
|
-
|
|||||
Reserve
for disputed and unallowable costs
|
||||||||||||||||
incurred
under government contracts
|
$
|
131
|
$
|
-
|
$
|
11 (b
|
)
|
$
|
(9
|
)
|
$
|
133
|
HALLIBURTON
COMPANY
|
|
By
|
/s/
David J. Lesar
|
David
J. Lesar
|
|
Chairman
of the Board,
|
|
President,
and Chief Executive Officer
|
|
Signature
|
Title
|
/s/
David J. Lesar
|
Chairman
of the Board, President,
|
David J. Lesar
|
Chief
Executive Officer, and Director
|
/s/
C. Christopher Gaut
|
Executive
Vice President and
|
C. Christopher Gaut
|
Chief
Financial Officer
|
/s/
Mark A. McCollum
|
Senior
Vice President and
|
Mark A. McCollum
|
Chief
Accounting Officer
|
Signature
|
Title
|
* Robert
L. Crandall
|
Director
|
Robert L. Crandall
|
|
* Kenneth
T. Derr
|
Director
|
Kenneth T. Derr
|
|
* S.
Malcolm Gillis
|
Director
|
S. Malcolm Gillis
|
|
* W.
R. Howell
|
Director
|
W.
R. Howell
|
|
* Ray
L. Hunt
|
Director
|
Ray L. Hunt
|
|
* J.
Landis Martin
|
Director
|
J.
Landis Martin
|
|
* Jay
A. Precourt
|
Director
|
Jay A. Precourt
|
|
* Debra
L. Reed
|
Director
|
Debra L. Reed
|
|
*
/s/ Margaret E. Carriere
|
|
Margaret E. Carriere, Attorney-in-fact
|