Edgar Filing: HALLIBURTON CO

edmarch200810q_final.htm

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

[X] Quarterly Report Pursuant to Section 13 or 15(d) of the

Securities Exchange Act of 1934

For the quarterly period ended March 31, 2008

[ ] Transition Report Pursuant to Section 13 or 15(d)

of the Securities Exchange Act of 1934

For the transition period from _____ to _____

Commission File Number 001-03492

HALLIBURTON COMPANY

(a Delaware Corporation)

75-2677995

5 Houston Center

1401 McKinney, Suite 2400

Houston, Texas 77010

(Address of Principal Executive Offices)

Telephone Number – Area Code (713) 759-2600

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes X No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer [X]

Non-accelerated filer [ ]

Accelerated filer [ ]

Smaller reporting company [ ]

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes No X

As of April 17, 2008, 872,373,534 shares of Halliburton Company common stock, $2.50 par value per share, were outstanding.

HALLIBURTON COMPANY

Index

		Page No.
PART I.	FINANCIAL INFORMATION

Item 1.	Financial Statements	3

	- Condensed Consolidated Statements of Operations	3
	- Condensed Consolidated Balance Sheets	4
	- Condensed Consolidated Statements of Cash Flows	5
	- Notes to Condensed Consolidated Financial Statements	6

Item 2.	Management’s Discussion and Analysis of Financial Condition and
	Results of Operations	17

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	32

Item 4.	Controls and Procedures	32

PART II.	OTHER INFORMATION

Item 1.	Legal Proceedings	33

Item 1(a).	Risk Factors	33

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	33

Item 3.	Defaults Upon Senior Securities	33

Item 4.	Submission of Matters to a Vote of Security Holders	33

Item 5.	Other Information	33

Item 6.	Exhibits	34

Signatures		35

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

HALLIBURTON COMPANY

Condensed Consolidated Statements of Operations

(Unaudited)


	Three Months Ended March 31
Millions of dollars and shares except per share data	2008			2007
Revenue:
Services	$	2,964		$	2,522
Product sales		1,065			900
Total revenue		4,029			3,422
Operating costs and expenses:
Cost of services		2,273			1,817
Cost of sales		873			749
General and administrative		72			69
Gain on sale of assets, net		(36	)		(1	)
Total operating costs and expenses		3,182			2,634
Operating income		847			788
Interest expense		(38	)		(38	)
Interest income		20			38
Other, net		(1	)		(3	)
Income from continuing operations before income taxes
and minority interest		828			785
Provision for income taxes		(238	)		(259	)
Minority interest in net (income) loss of subsidiaries		(7	)		3
Income from continuing operations		583			529
Income from discontinued operations, net of income tax
provision of $1 and $30		1			23
Net income	$	584		$	552
Basic income per share:
Income from continuing operations	$	0.67		$	0.53
Income from discontinued operations, net		–			0.02
Net income per share	$	0.67		$	0.55
Diluted income per share:
Income from continuing operations	$	0.64		$	0.52
Income from discontinued operations, net		–			0.02
Net income per share	$	0.64		$	0.54

Cash dividends per share	$	0.09		$	0.075
Basic weighted average common shares outstanding		873			992
Diluted weighted average common shares outstanding		911			1,025

See notes to condensed consolidated financial statements.

HALLIBURTON COMPANY

Condensed Consolidated Balance Sheets

(Unaudited)

	March 31,			December 31,
Millions of dollars and shares except per share data	2008			2007
Assets
Current assets:
Cash and equivalents	$	1,994		$	1,847
Receivables (less allowance for bad debts of $52 and $49)		3,301			3,093
Inventories		1,655			1,459
Current deferred income taxes		276			376
Investments in marketable securities		–			388
Other current assets		470			410
Total current assets		7,696			7,573
Property, plant, and equipment, net of accumulated depreciation of $4,268 and $4,126		3,851			3,630
Goodwill		803			790
Noncurrent deferred income taxes		192			348
Other assets		786			794
Total assets	$	13,328		$	13,135
Liabilities and Shareholders’ Equity
Current liabilities:
Accounts payable	$	907		$	768
Employee compensation and benefits		463			575
Deferred revenue		240			209
Income tax payable		209			209
Current maturities of long-term debt		172			159
Other current liabilities		491			491
Total current liabilities		2,482			2,411
Long-term debt		2,624			2,627
Employee compensation and benefits		394			403
Other liabilities		666			734
Total liabilities		6,166			6,175
Minority interest in consolidated subsidiaries		100			94
Shareholders’ equity:
Common shares, par value $2.50 per share – authorized 2,000 shares, issued 1,063 and 1,063
shares		2,659			2,657
Paid-in capital in excess of par value		1,759			1,741
Accumulated other comprehensive loss		(102	)		(104	)
Retained earnings		8,699			8,202
		13,015			12,496
Less 192 and 183 shares of treasury stock, at cost		5,953			5,630
Total shareholders’ equity		7,062			6,866
Total liabilities and shareholders’ equity	$	13,328		$	13,135

See notes to condensed consolidated financial statements.

HALLIBURTON COMPANY

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	Three Months Ended
	March 31
Millions of dollars	2008			2007
Cash flows from operating activities:
Net income	$	584		$	552
Adjustments to reconcile net income to net cash from operations:
Provision for deferred income taxes		174			13
Depreciation, depletion, and amortization		164			131
Gain on sale of assets		(36	)		(1	)
Impairment of assets		23			–
Income from discontinued operations		(1	)		(23	)
Other changes:
Inventories		(197	)		(194	)
Accounts payable		137			75
Receivables		(114	)		(64	)
Other		(210	)		95
Cash flows from discontinued operations		1			(143	)
Total cash flows from operating activities		525			441
Cash flows from investing activities:
Capital expenditures		(392	)		(303	)
Sales (purchases) of short-term investments in marketable securities, net		388			(834	)
Sales of property, plant, and equipment		43			39
Acquisitions of assets, net of cash acquired		(2	)		(180	)
Other investing activities		(14	)		(3	)
Cash flows from discontinued operations		–			(13	)
Total cash flows from investing activities		23			(1,294	)
Cash flows from financing activities:
Payments to reacquire common stock		(368	)		(8	)
Payments of dividends to shareholders		(80	)		(75	)
Proceeds from exercises of stock options		35			38
Other financing activities		8			15
Cash flows from discontinued operations		–			(18	)
Total cash flows from financing activities		(405	)		(48	)
Effect of exchange rate changes on cash		4			(5	)
Increase (decrease) in cash and equivalents		147			(906	)
Cash and equivalents at beginning of period, including $0 and $1,461 related to
discontinued operations		1,847			4,379
Cash and equivalents at end of period, including $0 and $1,287 related to
discontinued operations	$	1,994		$	3,473
Supplemental disclosure of cash flow information:
Cash payments during the period for:
Interest from continuing operations	$	46		$	44
Income taxes from continuing operations	$	95		$	76

See notes to condensed consolidated financial statements.

HALLIBURTON COMPANY

Notes to Condensed Consolidated Financial Statements

(Unaudited)

Note 1. Basis of Presentation

The accompanying unaudited condensed consolidated financial statements were prepared using generally accepted accounting principles for interim financial information and the instructions to Form 10-Q and Regulation S-X. Accordingly, these financial statements do not include all information or footnotes required by generally accepted accounting principles for annual financial statements and should be read together with our 2007 Annual Report on Form 10-K.

Certain prior period amounts have been reclassified to be consistent with the current presentation.

Our accounting policies are in accordance with generally accepted accounting principles in the United States of America. The preparation of financial statements in conformity with these accounting principles requires us to make estimates and assumptions that affect:

the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements; and

the reported amounts of revenue and expenses during the reporting period.

Ultimate results could differ from our estimates.

In our opinion, the condensed consolidated financial statements included herein contain all adjustments necessary to present fairly our financial position as of March 31, 2008, the results of our operations for the three months ended March 31, 2008 and 2007, and our cash flows for the three months ended March 31, 2008 and 2007. Such adjustments are of a normal recurring nature. The results of operations for the three months ended March 31, 2008 may not be indicative of results for the full year.

Note 2. KBR Separation

On April 5, 2007, we completed the separation of KBR from us by exchanging the 135.6 million shares of KBR common stock owned by us on that date for 85.3 million shares of our common stock. In the second quarter of 2007, we recorded a gain on the disposition of KBR of approximately $933 million, net of tax and the estimated fair value of the indemnities and guarantees provided to KBR as described below, which is included in income from discontinued operations on the consolidated statement of operations.

We entered into various agreements relating to the separation of KBR, including, among others, a master separation agreement, a registration rights agreement, a tax sharing agreement, transition services agreements, and an employee matters agreement. The master separation agreement provides for, among other things, KBR’s responsibility for liabilities related to its business and Halliburton’s responsibility for liabilities unrelated to KBR’s business. Halliburton provides indemnification in favor of KBR under the master separation agreement for certain contingent liabilities, including Halliburton’s indemnification of KBR and any of its greater than 50%-owned subsidiaries as of November 20, 2006, the date of the master separation agreement, for:

fines or other monetary penalties or direct monetary damages, including disgorgement, as a result of a claim made or assessed by a governmental authority in the United States, the United Kingdom, France, Nigeria, Switzerland, and/or Algeria, or a settlement thereof, related to alleged or actual violations occurring prior to November 20, 2006 of the United States Foreign Corrupt Practices Act (FCPA) or particular, analogous applicable foreign statutes, laws, rules, and regulations in connection with investigations pending as of that date, including with respect to the construction and subsequent expansion by TSKJ of a natural gas liquefaction complex and related facilities at Bonny Island in Rivers State, Nigeria; and

all out-of-pocket cash costs and expenses, or cash settlements or cash arbitration awards in lieu thereof, KBR may incur after the effective date of the master separation agreement as a result of the replacement of the subsea flowline bolts installed in connection with the Barracuda-Caratinga project. See Note 8 for further discussion of these matters.

As a result of these agreements, we recorded $190 million, as a reduction of the gain on the disposition of KBR, to reflect the estimated fair value of the above indemnities and guarantees, net of the associated estimated future tax benefit. The estimated fair value of these indemnities and guarantees is primarily included in “Other liabilities” on the condensed consolidated balance sheets at March 31, 2008 and December 31, 2007.

Additionally, Halliburton provides indemnities, performance guarantees, surety bond guarantees, and letter of credit guarantees that are currently in place in favor of KBR’s customers or lenders under project contract, credit agreements, letters of credit, and other KBR credit instruments. These indemnities and guarantees will continue until they expire at the earlier of: (1) the termination of the underlying project contract or KBR obligations thereunder; (2) the expiration of the relevant credit support instrument in accordance with its terms or release of such instrument by the customer; or (3) the expiration of the credit agreements. Further, KBR and we have agreed that, until December 31, 2009, we will issue additional guarantees, indemnification, and reimbursement commitments for KBR’s benefit in connection with: (a) letters of credit necessary to comply with KBR’s Egypt Basic Industries Corporation ammonia plant contract, KBR’s Allenby & Connaught project, and all other KBR project contracts that were in place as of December 15, 2005; (b) surety bonds issued to support new task orders pursuant to the Allenby & Connaught project, two job order contracts for KBR’s Government and Infrastructure segment, and all other KBR project contracts that were in place as of December 15, 2005; and (c) performance guarantees in support of these contracts. KBR is compensating Halliburton for these guarantees. Halliburton has also provided a limited indemnity, with respect to FCPA governmental and third-party claims, to the lender parties under KBR’s revolving credit agreement expiring in December 2010. KBR has agreed to indemnify Halliburton, other than for the FCPA and Barracuda-Caratinga bolts matter, if Halliburton is required to perform under any of the indemnities or guarantees related to KBR’s revolving credit agreement, letters of credit, surety bonds, or performance guarantees described above.

The tax sharing agreement provides for allocations of United States and certain other jurisdiction tax liabilities between us and KBR. Under the transition services agreements, we continue to provide various interim corporate support services to KBR, and KBR continues to provide various interim corporate support services to us. The fees are determined on a basis generally intended to approximate the fully allocated direct and indirect costs of providing the services, without any profit. Under an employee matters agreement, Halliburton and KBR have allocated liabilities and responsibilities related to current and former employees and their participation in certain benefit plans. Among other items, the employee matters agreement provided for the conversion, which occurred upon completion of the separation of KBR, of stock options and restricted stock awards (with restrictions that had not yet lapsed as of the final separation date) granted to KBR employees under our 1993 Stock and Incentive Plan (1993 Plan) to options and restricted stock awards covering KBR common stock. As of April 5, 2007, these awards consisted of 1.2 million options with a weighted average exercise price per share of $15.01 and approximately 600,000 restricted shares with a weighted average grant-date fair value per share of $17.95 under our 1993 Plan.

Note 3. Acquisitions and Dispositions

In March 2008, we completed the sale of a joint venture interest to our joint venture partner. As a result of the transaction, we recorded a gain of $35 million during the first quarter of 2008. We accounted for our interest in the joint venture using the cost method in our Completion and Production segment.

In July 2007, we acquired the entire share capital of PSL Energy Services Limited (PSLES), a leading eastern hemisphere provider of process, pipeline, and well intervention services. PSLES has operational bases in the United Kingdom, Norway, the Middle East, Azerbaijan, Algeria, and Asia Pacific. We paid approximately $332 million for PSLES, consisting of $328 million in cash and $4 million in debt assumed, subject to adjustment for working capital purposes. As of March 31, 2008, we had recorded goodwill of $166 million and intangible assets of $61 million on a preliminary basis until our analysis of the fair value of assets acquired and liabilities assumed is complete. Beginning in August 2007, PSLES’s results of operations are included in our Completion and Production segment.

In January 2007, we acquired all intellectual property, current assets, and existing business associated with Calgary-based Ultraline Services Corporation (Ultraline), a division of Savanna Energy Services Corp. Ultraline is a provider of wireline services in Canada. We paid approximately $178 million for Ultraline and recorded goodwill of $124 million and intangible assets of $41 million. Beginning in February 2007, Ultraline’s results of operations are included in our Drilling and Evaluation segment.

Note 4. Business Segment Information

We operate under two divisions, which form the basis for the two operating segments we report: the Completion and Production segment and the Drilling and Evaluation segment.

The following table presents information on our business segments. “Corporate and other” includes expenses related to support functions and corporate executives. Also included are certain gains and losses not attributable to a particular business segment.

Intersegment revenue was immaterial. Our equity in earnings and losses of unconsolidated affiliates that are accounted for by the equity method is included in revenue and operating income of the applicable segment.

	Three Months Ended March 31
Millions of dollars	2008			2007
Revenue:
Completion and Production	$	2,191		$	1,844
Drilling and Evaluation		1,838			1,578
Total revenue	$	4,029		$	3,422

Operating income (loss):
Completion and Production	$	529		$	477
Drilling and Evaluation		384			362
Total operations		913			839
Corporate and other		(66	)		(51	)
Total operating income	$	847		$	788

As of March 31, 2008, 33% of our gross trade receivables were from customers in the United States. As of December 31, 2007, 35% of our gross trade receivables were from customers in the United States. No other country accounted for more than 10% of our gross trade receivables at these dates.

Note 5. Inventories

Inventories are stated at the lower of cost or market. In the United States, we manufacture certain finished products and have parts inventories for drill bits, completion products, bulk materials, and other tools that are recorded using the last-in, first-out method totaling $79 million at March 31, 2008 and $71 million at December 31, 2007. If the average cost method was used, total inventories would have been $27 million higher than reported at March 31, 2008 and $25 million higher than reported at December 31, 2007. Inventories consisted of the following:

	March 31,		December 31,
Millions of dollars	2008		2007
Finished products and parts	$	1,143	$	1,042
Raw materials and supplies		415		325
Work in process		97		92
Total	$	1,655	$	1,459

Finished products and parts are reported net of obsolescence reserves of $74 million at March 31, 2008 and $65 million at December 31, 2007.

Note 6. Debt

In the first quarter of 2008, the stock conversion rate for the $1.2 billion of 3.125% convertible senior notes issued in June 2003 changed to 53.3768 shares of common stock per each $1,000 principal amount of the convertible senior notes due to the increased quarterly dividend paid on our common stock.

Note 7. Comprehensive Income

The components of other comprehensive income included the following:

	Three Months Ended
	March 31
Millions of dollars	2008			2007
Net income	$	584		$	552
Net cumulative translation adjustments		1			(1	)
Realized defined benefit and other postretirement plans adjustments, net		3			11
Net unrealized gains (losses) on investments		(2	)		1
Total comprehensive income	$	586		$	563

Accumulated other comprehensive loss consisted of the following:

	March 31,			December 31,
Millions of dollars	2008			2007
Cumulative translation adjustments	$	(60	)	$	(61	)
Defined benefit and other postretirement liability adjustments		(42	)		(45	)
Unrealized gains on investments and derivatives		-			2
Total accumulated other comprehensive loss	$	(102	)	$	(104	)

Note 8. Commitments and Contingencies

Foreign Corrupt Practices Act investigations

The Securities and Exchange Commission (SEC) is conducting a formal investigation into whether improper payments were made to government officials in Nigeria through the use of agents or subcontractors in connection with the construction and subsequent expansion by TSKJ of a multibillion dollar natural gas liquefaction complex and related facilities at Bonny Island in Rivers State, Nigeria. The Department of Justice (DOJ) is also conducting a related criminal investigation. The SEC has also issued subpoenas seeking information, which we and KBR are furnishing, regarding current and former agents used in connection with multiple projects, including current and prior projects, over the past 20 years located both in and outside of Nigeria in which the Halliburton energy services business, KBR or affiliates, subsidiaries or joint ventures of Halliburton or KBR, are or were participants. In September 2006 and October 2007, the SEC and the DOJ, respectively, each requested that we enter into an agreement to extend the statute of limitations with respect to its investigation. We have entered into tolling agreements with the SEC and the DOJ.

TSKJ is a private limited liability company registered in Madeira, Portugal whose members are Technip SA of France, Snamprogetti Netherlands B.V. (a subsidiary of Saipem SpA of Italy), JGC Corporation of Japan, and Kellogg Brown & Root LLC (a subsidiary of KBR), each of which had an approximate 25% interest in the venture. TSKJ and other similarly owned entities entered into various contracts to build and expand the liquefied natural gas project for Nigeria LNG Limited, which is owned by the Nigerian National Petroleum Corporation, Shell Gas B.V., Cleag Limited (an affiliate of Total), and Agip International B.V. (an affiliate of ENI SpA of Italy).

The SEC and the DOJ have been reviewing these matters in light of the requirements of the FCPA. In addition to performing our own investigation, we have been cooperating with the SEC and the DOJ investigations and with other investigations in France, Nigeria, and Switzerland regarding the Bonny Island project. The government of Nigeria gave notice in 2004 to the French magistrate of a civil claim as an injured party in the French investigation. We also believe that the Serious Fraud Office in the United Kingdom is conducting an investigation relating to the Bonny Island project. Our Board of Directors has appointed a committee of independent directors to oversee and direct the FCPA investigations.

The matters under investigation relating to the Bonny Island project cover an extended period of time (in some cases significantly before our 1998 acquisition of Dresser Industries and continuing through the current time period). We have produced documents to the SEC and the DOJ from the files of numerous officers and employees of Halliburton and KBR, including current and former executives of Halliburton and KBR, both voluntarily and pursuant to company subpoenas from the SEC and a grand jury, and we are making our employees and we understand KBR is making its employees available to the SEC and the DOJ for interviews. In addition, the SEC has issued a subpoena to A. Jack Stanley, who formerly served as a consultant and chairman of Kellogg Brown & Root LLC, and to others, including certain of our and KBR’s current or former executive officers or employees, and at least one subcontractor of KBR. We further understand that the DOJ has issued subpoenas for the purpose of obtaining information abroad, and we understand that other partners in TSKJ have provided information to the DOJ and the SEC with respect to the investigations, either voluntarily or under subpoenas.

The SEC and DOJ investigations include an examination of whether TSKJ’s engagements of Tri-Star Investments as an agent and a Japanese trading company as a subcontractor to provide services to TSKJ were utilized to make improper payments to Nigerian government officials. In connection with the Bonny Island project, TSKJ entered into a series of agency agreements, including with Tri-Star Investments, of which Jeffrey Tesler is a principal, commencing in 1995 and a series of subcontracts with a Japanese trading company commencing in 1996. We understand that a French magistrate has officially placed Mr. Tesler under investigation for corruption of a foreign public official. In Nigeria, a legislative committee of the National Assembly and the Economic and Financial Crimes Commission, which is organized as part of the executive branch of the government, are also investigating these matters. Our representatives have met with the French magistrate and Nigerian officials. In October 2004, representatives of TSKJ voluntarily testified before the Nigerian legislative committee.

TSKJ suspended the receipt of services from and payments to Tri-Star Investments and the Japanese trading company and has considered instituting legal proceedings to declare all agency agreements with Tri-Star Investments terminated and to recover all amounts previously paid under those agreements. In February 2005, TSKJ notified the Attorney General of Nigeria that TSKJ would not oppose the Attorney General’s efforts to have sums of money held on deposit in accounts of Tri-Star Investments in banks in Switzerland transferred to Nigeria and to have the legal ownership of such sums determined in the Nigerian courts.

As a result of these investigations, information has been uncovered suggesting that, commencing at least 10 years ago, members of TSKJ planned payments to Nigerian officials. We have reason to believe that, based on the ongoing investigations, payments may have been made by agents of TSKJ to Nigerian officials. The government has recently confirmed that it has evidence of such payments. The government has also recently advised Halliburton and KBR that it has evidence of payments to Nigerian officials by another agent in connection with a separate KBR-managed project in Nigeria called the Shell EA project and possibly evidence of payments in connection with other projects in Nigeria, potentially including energy services projects. In addition, information uncovered in the summer of 2006 suggests that, prior to 1998, plans may have been made by employees of The M.W. Kellogg Company (a predecessor of a KBR subsidiary) to make payments to government officials in connection with the pursuit of a number of other projects in countries outside of Nigeria. We are reviewing a number of more recently discovered documents related to KBR’s activities in countries outside of Nigeria with respect to agents for projects after 1998. Certain activities discussed in this paragraph involve current or former employees or persons who were or are consultants to KBR, and our investigation is continuing.

In June 2004, all relationships with Mr. Stanley and another consultant and former employee of M.W. Kellogg Limited were terminated. The terminations occurred because of Code of Business Conduct violations that allegedly involved the receipt of improper personal benefits from Mr. Tesler in connection with TSKJ’s construction of the Bonny Island project.

In 2006 and 2007, KBR or Halliburton suspended the services of two agents in and outside of Nigeria, including the agent in connection with the Shell EA project and another agent who, until such suspension, had worked for KBR outside of Nigeria on several current projects and on numerous older projects going back to the early 1980s. Such suspensions have occurred when possible improper conduct has been discovered or alleged or when Halliburton and KBR have been unable to confirm the agent’s compliance with applicable law and the Code of Business Conduct.

The SEC and DOJ are also investigating and have issued subpoenas concerning TSKJ's use of an immigration services provider, apparently managed by a Nigerian immigration official, to which approximately $1.8 million in payments in excess of costs of visas were allegedly made between approximately 1997 and the termination of the provider in December 2004. We understand that TSKJ terminated the immigration services provider after a KBR employee discovered the issue. We reported this matter to the United States government in 2007. The SEC has issued a subpoena requesting documents among other things concerning any payment of anything of value to Nigerian government officials. In response to such subpoena, we have produced and continue to produce additional documents regarding KBR and Halliburton’s energy services business use of immigration and customs service providers, which may result in further inquiries. Furthermore, as a result of these matters, we have expanded our own investigation to consider any matters raised by energy services activities in Nigeria.

If violations of the FCPA were found, a person or entity found in violation could be subject to fines, civil penalties of up to $500,000 per violation, equitable remedies, including disgorgement (if applicable) generally of profits, including prejudgment interest on such profits, causally connected to the violation, and injunctive relief. Criminal penalties could range up to the greater of $2 million per violation or twice the gross pecuniary gain or loss from the violation, which could be substantially greater than $2 million per violation. It is possible that both the SEC and the DOJ could assert that there have been multiple violations, which could lead to multiple fines. The amount of any fines or monetary penalties that could be assessed would depend on, among other factors, the findings regarding the amount, timing, nature, and scope of any improper payments, whether any such payments were authorized by or made with knowledge of us, KBR or our or KBR’s affiliates, the amount of gross pecuniary gain or loss involved, and the level of cooperation provided the government authorities during the investigations. The government has expressed concern regarding the level of our cooperation. Agreed dispositions of these types of violations also frequently result in an acknowledgement of wrongdoing by the entity and the appointment of a monitor on terms negotiated with the SEC and the DOJ to review and monitor current and future business practices, including the retention of agents, with the goal of assuring compliance with the FCPA.

These investigations could also result in third-party claims against us, which may include claims for special, indirect, derivative or consequential damages, damage to our business or reputation, loss of, or adverse effect on, cash flow, assets, goodwill, results of operations, business prospects, profits or business value or claims by directors, officers, employees, affiliates, advisors, attorneys, agents, debt holders, or other interest holders or constituents of us or our current or former subsidiaries. In addition, we could incur costs and expenses for any monitor required by or agreed to with a governmental authority to review our continued compliance with FCPA law.

As of March 31, 2008, we are unable to estimate an amount of probable loss or a range of possible loss related to these matters as it relates to Halliburton directly. However, we provided indemnification in favor of KBR under the master separation agreement for certain contingent liabilities, including Halliburton’s indemnification of KBR and any of its greater than 50%-owned subsidiaries as of November 20, 2006, the date of the master separation agreement, for fines or other monetary penalties or direct monetary damages, including disgorgement, as a result of a claim made or assessed by a governmental authority in the United States, the United Kingdom, France, Nigeria, Switzerland, and/or Algeria, or a settlement thereof, related to alleged or actual violations occurring prior to November 20, 2006 of the FCPA or particular, analogous applicable foreign statutes, laws, rules, and regulations in connection with investigations pending as of that date, including with respect to the construction and subsequent expansion by TSKJ of a natural gas liquefaction complex and related facilities at Bonny Island in Rivers State, Nigeria. We recorded the estimated fair market value of this indemnity regarding FCPA matters described above upon our separation from KBR. See Note 2 for additional information.

Our indemnification obligation to KBR does not include losses resulting from third-party claims against KBR, including claims for special, indirect, derivative or consequential damages, nor does our indemnification apply to damage to KBR’s business or reputation, loss of, or adverse effect on, cash flow, assets, goodwill, results of operations, business prospects, profits or business value or claims by directors, officers, employees, affiliates, advisors, attorneys, agents, debt holders, or other interest holders or constituents of KBR or KBR’s current or former subsidiaries.

In consideration of our agreement to indemnify KBR for the liabilities referred to above, KBR has agreed that we will at all times, in our sole discretion, have and maintain control over the investigation, defense and/or settlement of these FCPA matters until such time, if any, that KBR exercises its right to assume control of the investigation, defense and/or settlement of the FCPA matters as it relates to KBR. KBR has also agreed, at our expense, to assist with Halliburton’s full cooperation with any governmental authority in our investigation of these FCPA matters and our investigation, defense and/or settlement of any claim made by a governmental authority or court relating to these FCPA matters, in each case even if KBR assumes control of these FCPA matters as it relates to KBR. If KBR takes control over the investigation, defense, and/or settlement of FCPA matters, refuses a settlement of FCPA matters negotiated by us, enters into a settlement of FCPA matters without our consent, or materially breaches its obligation to cooperate with respect to our investigation, defense, and/or settlement of FCPA matters, we may terminate the indemnity.

Barracuda-Caratinga arbitration

We also provided indemnification in favor of KBR under the master separation agreement for all out-of-pocket cash costs and expenses (except for legal fees and other expenses of the arbitration so long as KBR controls and directs it), or cash settlements or cash arbitration awards in lieu thereof, KBR may incur after November 20, 2006 as a result of the replacement of certain subsea flowline bolts installed in connection with the Barracuda-Caratinga project. Under the master separation agreement, KBR currently controls the defense, counterclaim, and settlement of the subsea flowline bolts matter. As a condition of our indemnity, for any settlement to be binding upon us, KBR must secure our prior written consent to such settlement’s terms. We have the right to terminate the indemnity in the event KBR enters into any settlement without our prior written consent. See Note 2 for additional information regarding the KBR indemnification.

At Petrobras’ direction, KBR replaced certain bolts located on the subsea flowlines that failed through mid-November 2005, and KBR has informed us that additional bolts have failed thereafter, which were replaced by Petrobras. These failed bolts were identified by Petrobras when it conducted inspections of the bolts. A key issue in the arbitration is which party is responsible for the designation of the material to be used for the bolts. We understand that KBR believes that an instruction to use the particular bolts was issued by Petrobras, and as such, KBR believes the cost resulting from any replacement is not KBR’s responsibility. We understand Petrobras disagrees. We understand KBR believes several possible solutions may exist, including replacement of the bolts. Estimates indicate that costs of these various solutions range up to $140 million. In March 2006, Petrobras commenced arbitration against KBR claiming $220 million plus interest for the cost of monitoring and replacing the defective bolts and all related costs and expenses of the arbitration, including the cost of attorneys’ fees. We understand KBR is vigorously defending and pursuing recovery of the costs incurred to date through the arbitration process and to that end has submitted a counterclaim in the arbitration seeking the recovery of $22 million. The arbitration panel held an evidentiary hearing during the week of March 31, 2008 and took evidence and arguments under advisement.

Securities and related litigation

In June 2002, a class action lawsuit was filed against us in federal court alleging violations of the federal securities laws after the SEC initiated an investigation in connection with our change in accounting for revenue on long-term construction projects and related disclosures. In the weeks that followed, approximately twenty similar class actions were filed against us. Several of those lawsuits also named as defendants several of our present or former officers and directors. The class action cases were later consolidated, and the amended consolidated class action complaint, styled Richard Moore, et al. v. Halliburton Company, et al., was filed and served upon us in April 2003. As a result of a substitution of lead plaintiffs, the case is now styled Archdiocese of Milwaukee Supporting Fund (“AMSF”) v. Halliburton Company, et al. We settled with the SEC in the second quarter of 2004.

In early May 2003, we entered into a written memorandum of understanding setting forth the terms upon which the Moore class action would be settled. In June 2003, the lead plaintiffs filed a motion for leave to file a second amended consolidated complaint, which was granted by the court. In addition to restating the original accounting and disclosure claims, the second amended consolidated complaint included claims arising out of the 1998 acquisition of Dresser Industries, Inc. by Halliburton, including that we failed to timely disclose the resulting asbestos liability exposure (the “Dresser claims”). The memorandum of understanding contemplated settlement of the Dresser claims as well as the original claims.

In June 2004, the court entered an order preliminarily approving the settlement. Following the transfer of the case to another district judge, the court held that evidence of the settlement’s fairness was inadequate, denied the motion for final approval of the settlement, and ordered the parties to mediate. The mediation was unsuccessful.

In April 2005, the court appointed new co-lead counsel and named AMSF the new lead plaintiff, directing that it file a third consolidated amended complaint and that we file our motion to dismiss. The court held oral arguments on that motion in August 2005, at which time the court took the motion under advisement. In March 2006, the court entered an order in which it granted the motion to dismiss with respect to claims arising prior to June 1999 and granted the motion with respect to certain other claims while permitting AMSF to re-plead some of those claims to correct deficiencies in its earlier complaint. In April 2006, AMSF filed its fourth amended consolidated complaint. We filed a motion to dismiss those portions of the complaint that had been re-pled. A hearing was held on that motion in July 2006, and in March 2007 the court ordered dismissal of the claims against all individual defendants other than our CEO. The court ordered that the case proceed against our CEO and Halliburton. In response to a motion by the lead plaintiff, on February 26, 2007, the court ordered the removal and replacement of their co-lead counsel. In June 2007, upon becoming aware of a United States Supreme Court opinion issued in that month, the court allowed further briefing on the motion to dismiss filed on behalf of our CEO. The court again denied the motion to dismiss in March 2008. In September 2007, AMSF filed a motion for class certification, and our response was filed in November 2007. A hearing was held in March 2008, and we await the court’s ruling. The case is set for trial in July 2009.

As of March 31, 2008, we had not accrued any amounts related to this matter because we do not believe that a loss is probable. Further, an estimate of possible loss or range of loss related to this matter cannot be made.

Asbestos insurance settlements

At December 31, 2004, we resolved all open and future asbestos- and silica-related claims in the prepackaged Chapter 11 proceedings of DII Industries LLC, Kellogg Brown & Root LLC, and our other affected subsidiaries that had previously been named as defendants in a large number of asbestos- and silica-related lawsuits. During 2004, we settled insurance disputes with substantially all the insurance companies for asbestos- and silica-related claims and all other claims under the applicable insurance policies and terminated all the applicable insurance policies.

Under the insurance settlements entered into as part of the resolution of our Chapter 11 proceedings, we have agreed to indemnify our insurers under certain historic general liability insurance policies in certain situations. We have concluded that the likelihood of any claims triggering the indemnity obligations is remote, and we believe any potential liability for these indemnifications will be immaterial. Further, an estimate of possible loss or range of loss related to this matter cannot be made. At March 31, 2008, we had not recorded any liability associated with these indemnifications.

M-I, LLC antitrust litigation

On February 16, 2007, we were informed that M-I, LLC, a competitor of ours in the drilling fluids market, had sued us for allegedly attempting to monopolize the market for invert emulsion drilling fluids used in deep water and/or in cold water temperatures. The claims M-I, LLC asserted were based upon its allegation that the patent issued for our Accolade® drilling fluid was invalid as a result of its allegedly having been procured by fraud on the United States Patent and Trademark Office and that our subsequent prosecution of an infringement action against M-I, LLC amounted to predatory conduct in violation of Section 2 of the Sherman Antitrust Act. M-I, LLC also alleged that we falsely advertised our Accolade® drilling fluid in violation of the Lanham Act and California law and that our earlier infringement action amounted to malicious prosecution in violation of Texas state law. This case was settled in the first quarter of 2008 for an immaterial amount.

Dirt, Inc. litigation

In April 2005, Dirt, Inc. brought suit in Alabama against Bredero-Shaw (a joint venture in which we formerly held a 50% interest that we sold to the other party in the venture, ShawCor Ltd., in 2002), Halliburton Energy Services, Inc., and ShawCor Ltd., claiming that Bredero-Shaw disposed of hazardous waste in a construction materials landfill owned and operated by Dirt, Inc. Bredero-Shaw has offered to take responsibility for cleanup of the site. The plaintiff did not accept that offer, and the method and cost of such cleanup are disputed, with expert opinions ranging from $6 million to $144 million. On November 1, 2007, the trial court in the above-referenced matter entered a judgment in the total amount of $108 million, of which Halliburton Energy Services, Inc. could be responsible for as much as 50%. We are pursuing an appeal and believe that it is probable that the Alabama Supreme Court will reverse the trial court’s judgment because, among other things:

the trial court misapplied the law on the measure of damages;

Halliburton Energy Services, Inc., as a shareholder, should not have liability for actions of the venture; and

the statute of limitations had run on an issue submitted to the jury.

We have accrued an amount less than $10 million, which represents our 50% portion of what we believe it will cost to remediate the site.

Environmental

We are subject to numerous environmental, legal, and regulatory requirements related to our operations worldwide. In the United States, these laws and regulations include, among others:

the Comprehensive Environmental Response, Compensation, and Liability Act;

the Resource Conservation and Recovery Act;

the Clean Air Act;

the Federal Water Pollution Control Act; and

the Toxic Substances Control Act.

In addition to the federal laws and regulations, states and other countries where we do business often have numerous environmental, legal, and regulatory requirements by which we must abide. We evaluate and address the environmental impact of our operations by assessing and remediating contaminated properties in order to avoid future liabilities and comply with environmental, legal, and regulatory requirements. On occasion, we are involved in specific environmental litigation and claims, including the remediation of properties we own or have operated, as well as efforts to meet or correct compliance-related matters. Our Health, Safety and Environment group has several programs in place to maintain environmental leadership and to prevent the occurrence of environmental contamination.

We do not expect costs related to these remediation requirements to have a material adverse effect on our consolidated financial position or our results of operations. Our accrued liabilities for environmental matters were $70 million as of March 31, 2008 and $72 million as of December 31, 2007. Our total liability related to environmental matters covers numerous properties, including the property in regard to which Dirt, Inc. has brought suit against Bredero-Shaw (a joint venture in which we formerly held a 50% interest that we sold to the other party in the venture, ShawCor Ltd., in 2002), Halliburton Energy Services, Inc., and ShawCor Ltd. See “Dirt, Inc. litigation” in this note for further information regarding this matter.

We have subsidiaries that have been named as potentially responsible parties along with other third parties for 9 federal and state superfund sites for which we have established a liability. As of March 31, 2008, those 9 sites accounted for approximately $10 million of our total $70 million liability. For any particular federal or state superfund site, since our estimated liability is typically within a range and our accrued liability may be the amount on the low end of that range, our actual liability could eventually be well in excess of the amount accrued. Despite attempts to resolve these superfund matters, the relevant regulatory agency may at any time bring suit against us for amounts in excess of the amount accrued. With respect to some superfund sites, we have been named a potentially responsible party by a regulatory agency; however, in each of those cases, we do not believe we have any material liability. We also could be subject to third-party claims with respect to environmental matters for which we have been named as a potentially responsible party.

Letters of credit

In the normal course of business, we have agreements with banks under which approximately $2.4 billion of letters of credit, surety bonds, or bank guarantees were outstanding as of March 31, 2008, including $1.1 billion that relate to KBR. These KBR letters of credit, surety bonds, or bank guarantees are being guaranteed by us in favor of KBR’s customers and lenders. KBR has agreed to compensate us for these guarantees and indemnify us if we are required to perform under any of these guarantees. Some of the outstanding letters of credit have triggering events that would entitle a bank to require cash collateralization.

Note 9. Income per Share

Basic income per share is based on the weighted average number of common shares outstanding during the period. Diluted income per share includes additional common shares that would have been outstanding if potential common shares with a dilutive effect had been issued. A reconciliation of the number of shares used for the basic and diluted income per share calculations is as follows:

	Three Months Ended March 31
Millions of shares	2008		2007
Basic weighted average common shares outstanding		873		992
Dilutive effect of:
Convertible senior notes premium		31		24
Stock options		6		7
Restricted stock		1		2
Diluted weighted average common shares outstanding		911		1,025

Excluded from the computation of diluted income per share are options to purchase four million shares of common stock that were outstanding during the three months ended March 31, 2008 and options to purchase three million shares that were outstanding during the three months ended March 31, 2007. These options were outstanding during these quarters but were excluded because they were antidilutive, as the option exercise price was greater than the average market price of the common shares.

Effective April 5, 2007, common shares outstanding were reduced by the 85.3 million shares of our common stock that we accepted in exchange for the shares of KBR common stock we owned.

Note 10. Retirement Plans

The components of net periodic benefit cost related to pension benefits for the three months ended March 31, 2008 and March 31, 2007 were as follows:

	Three Months Ended March 31
	2008						2007
Millions of dollars	United States			International			United States			International
Service cost	$	–		$	7		$	–		$	6
Interest cost		2			13			2			11
Expected return on plan assets		(2	)		(11	)		(2	)		(9	)
Settlements/curtailments		–			–			–			(1	)
Amortization of unrecognized loss		1			1			1			2
Net periodic benefit cost	$	1		$	10		$	1		$	9

We currently expect to contribute approximately $28 million to our international pension plans in 2008. During the three months ended March 31, 2008, we contributed $16 million to our international pension plans. We do not have a required minimum contribution for our domestic plans; however, we may make additional discretionary contributions.

The components of net periodic benefit cost related to other postretirement benefits for the three months ended March 31, 2008 and March 31, 2007 were as follows:

	Three Months Ended March 31
Millions of dollars	2008			2007
Service cost	$	–		$	–
Interest cost		1			2
Unrecognized actuarial loss		(1	)		–
Net periodic benefit cost	$	–		$	2

Note 11. Common Stock

In February 2006, our Board of Directors approved a share repurchase program of up to $1.0 billion. In September 2006, our Board of Directors approved an increase to our existing common share repurchase program of up to an additional $2.0 billion. In July 2007, our Board of Directors approved an additional increase to our existing common share repurchase program of up to $2.0 billion, bringing the entire authorization to $5.0 billion. This additional authorization may be used for open market share purchases or to settle the conversion premium on our 3.125% convertible senior notes, should they be redeemed. From the inception of this program, we have repurchased approximately 89 million shares of our common stock for approximately $3.0 billion at an average price of $34.28 per share. These amounts include the repurchases of approximately 10 million shares of our common stock for approximately $360 million at an average price of $37.26 per share during the first quarter of 2008. As of March 31, 2008, approximately $2.0 billion remained available under this program.

Note 12. New Accounting Standards

In March 2008, the Financial Accounting Standards Board (FASB) issued Statement of Financial Accounting Standards (SFAS) No. 161, “Disclosure about Derivative Instruments and Hedging Activities – An Amendment of FASB Statement No. 133.” SFAS No. 161 requires more disclosures about an entity’s derivative and hedging activities in order to improve the transparency of financial reporting. SFAS No. 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early application encouraged. This Statement encourages, but does not require, comparative disclosures for earlier periods at initial adoption. We will adopt the provisions of SFAS No. 161 on January 1, 2009, which we do not expect will have a material impact on our consolidated financial statements.

In September 2006, the FASB issued SFAS No. 157, “Fair Value Measurements,” which is intended to increase consistency and comparability in fair value measurements by defining fair value, establishing a framework for measuring fair value, and expanding disclosures about fair value measurements. SFAS No. 157 applies to other accounting pronouncements that require or permit fair value measurements and is effective for financial statements issued for fiscal years beginning after November 15, 2007 and interim periods within those fiscal years. In February 2008, the FASB issued FASB Staff Position (FSP) FAS 157-1, “Application of FASB Statement No. 157 to FASB Statement No. 13 and Other Accounting Pronouncements That Address Fair Value Measurements for Purposes of Lease Classification or Measurement under Statement 13,” which removes certain leasing transactions from the scope of SFAS No. 157, and FSP FAS 157-2, “Effective Date of FASB Statement No. 157,” which defers the effective date of SFAS No. 157 for one year for certain nonfinancial assets and nonfinancial liabilities, except those that are recognized or disclosed at fair value in the financial statements on a recurring basis. On January 1, 2008, we adopted without material impact on our consolidated financial statements the provisions of SFAS No. 157 related to financial assets and liabilities and to nonfinancial assets and liabilities measured at fair value on a recurring basis. Beginning January 1, 2009, we will adopt the provisions for nonfinancial assets and nonfinancial liabilities that are not required or permitted to be measured at fair value on a recurring basis, which include those measured at fair value in goodwill impairment testing, indefinite-lived intangible assets measured at fair value for impairment assessment, nonfinancial long-lived assets measured at fair value for impairment assessment, asset retirement obligations initially measured at fair value, and those initially measured at fair value in a business combination. We do not expect the provisions of SFAS No. 157 related to these items to have a material impact on our consolidated financial statements.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

EXECUTIVE OVERVIEW

During the first quarter of 2008, our continuing operations produced revenue of $4.0 billion and operating income of $847 million, reflecting an operating margin of 21%. Revenue increased $607 million or 18% over the first quarter of 2007, while operating income improved $59 million or 7% over the first quarter of 2007. Consistent with our initiative to grow our non-North America operations, we experienced 24% revenue growth and 21% operating income growth outside of North America in the first quarter of 2008 compared to the first quarter of 2007. Revenue from our Latin America region increased 26% to $509 million and operating income increased 45% to $107 million in the first quarter of 2008 compared to the first quarter of 2007. Our Middle East/Asia and Europe/Africa/CIS regions also returned revenue growth in excess of 20% in the first quarter of 2008 compared to the first quarter of 2007.

Business outlook

The outlook for our business remains generally favorable. During 2007, the North America region experienced challenging market conditions as a result of downward pressure on pricing, as well as reduced activity in Canada. During the first quarter of 2008, operating margins in the region declined from prior quarter levels, primarily as a result of lower effective pricing for our United States fracturing services and cost inflation for fuel and fuel-based supplies and services. However, Canadian activity improved. Overall, we believe the strengthening in commodity prices in North America, particularly natural gas prices, will likely cause our customers to reevaluate their drilling plans for the latter half of 2008. We expect this to lead to increased North American activity during the second half of 2008.

Outside of North America, our outlook remains positive. Worldwide demand for hydrocarbons continues to grow, and the reservoirs are becoming more complex. The trend toward exploration and exploitation of more complex reservoirs bodes well for the mix of our product line offerings and degree of service intensity on a per rig basis. Therefore, we have been investing and will continue to invest in infrastructure, capital, and technology predominantly outside of North America, consistent with our initiative to grow our operations in that part of the world. In addition, we believe our Latin America region will experience the highest growth rate of all our regions, driven by contract awards in Mexico and higher activity in Colombia, Brazil, and Argentina.

In 2008, we are focusing on:

maintaining optimal utilization of our equipment and resources;

managing pricing, particularly in our North America operations;

hiring and training additional personnel to meet the increased demand for our services;

continuing the globalization of our manufacturing and supply chain processes;

balancing our United States operations by capitalizing on the trend toward horizontal drilling;

leveraging our technologies to provide our customers with the ability to more efficiently drill and complete their wells and to increase their productivity. To that end, we opened one international research and development center with global technology and training missions in 2007 and opened another in the first quarter of 2008;

maximizing our position to win meaningful international tenders, especially in deepwater fields, complex reservoirs, and high-pressure/high-temperature environments;

cultivating our relationships with national oil companies;

pursuing strategic acquisitions that enhance our technological position and our product and service portfolio in key geographic areas. We are currently conducting due diligence on a possible offer for Expro International Group PLC, a publicly traded oil services company in the United Kingdom, which may or may not lead to an offer; and

directing our capital spending primarily toward non-North America operations for service equipment additions and infrastructure. Capital spending for 2008 is expected to be approximately $1.7 billion to $1.8 billion.

Our operating performance is described in more detail in “Business Environment and Results of Operations.”

Foreign Corrupt Practices Act investigations

The Securities and Exchange Commission (SEC) is conducting a formal investigation into whether improper payments were made to government officials in Nigeria. The Department of Justice (DOJ) is also conducting a related criminal investigation. See Note 8 to our condensed consolidated financial statements for further information.

LIQUIDITY AND CAPITAL RESOURCES

We ended the first quarter of 2008 with cash and equivalents of $2.0 billion compared to $1.8 billion at December 31, 2007.

Significant sources of cash

Cash flows from operating activities contributed $525 million to cash in the first quarter of 2008. Growth in revenue and operating income in the first quarter of 2008 compared to the first quarter of 2007 is attributable to higher customer demand and increased service intensity due to a trend toward exploration and exploitation of more complex reservoirs.

During the first quarter of 2008, we sold approximately $388 million of marketable securities, consisting of auction-rate securities and variable-rate demand notes.

Further available sources of cash. On July 9, 2007, we entered into a new unsecured $1.2 billion five-year revolving credit facility that replaced our then existing unsecured $1.2 billion five-year revolving credit facility. The purpose of the new facility is to provide commercial paper support, general working capital, and credit for other corporate purposes. There were no cash drawings under the facility as of March 31, 2008.

Significant uses of cash

Capital expenditures were $392 million in the first quarter of 2008, with increased focus toward building infrastructure and adding service equipment in support of our expanding operations outside of North America. Capital expenditures were predominantly made in the drilling services, production enhancement, cementing, and wireline and perforating product service lines.

During the first quarter of 2008, we repurchased approximately 10 million shares of our common stock under our share repurchase program at a cost of approximately $360 million at an average price of $37.26 per share.

We paid $80 million in dividends to our shareholders in the first quarter of 2008.

Future uses of cash. In July 2007, our Board of Directors approved an increase to our existing common share repurchase program of up to an additional $2.0 billion, bringing the entire authorization to $5.0 billion. This additional authorization may be used for open market share purchases or to settle the conversion premium over the face amount of our 3.125% convertible senior notes, should they be redeemed. As of March 31, 2008, approximately $2.0 billion remained available under our share repurchase authorization.

Capital spending for 2008 is expected to be approximately $1.7 billion to $1.8 billion. The capital expenditures plan for 2008 is primarily directed toward our drilling services, wireline and perforating, production enhancement, and cementing operations. We will continue to explore opportunities for acquisitions that will enhance or augment our current portfolio of products and services, including those with unique technologies or distribution networks in areas where we do not already have large operations. Further, as market conditions change, we will continue to evaluate the allocation of our cash between acquisitions and stock buybacks in order to provide good return for our shareholders.

Our 3.125% convertible senior notes become redeemable at our option on or after July 15, 2008. If we choose to redeem the notes prior to their maturity or if the holders choose to convert the notes, we must settle the principal amount of the notes, which totaled $1.2 billion at March 31, 2008, in cash. We have the option to settle any amounts due in excess of the principal, which totaled approximately $1.6 billion at March 31, 2008, by delivering shares of our common stock, cash, or a combination of common stock and cash.

Subject to Board of Directors approval, we expect to pay dividends of approximately $80 million per quarter in 2008.

We are currently evaluating possible acquisitions, including Expro International Group PLC, which may result in additional borrowings and a significant use of cash.

Other factors affecting liquidity

Letters of credit. In the normal course of business, we have agreements with banks under which approximately $2.4 billion of letters of credit, surety bonds, or bank guarantees were outstanding as of March 31, 2008, including $1.1 billion that relate to KBR. These KBR letters of credit, surety bonds, or bank guarantees are being guaranteed by us in favor of KBR’s customers and lenders. KBR has agreed to compensate us for these guarantees and indemnify us if we are required to perform under any of these guarantees. Some of the outstanding letters of credit have triggering events that would entitle a bank to require cash collateralization.

Credit ratings. The credit ratings for our long-term debt are A2 with Moody’s Investors Service and A with Standard & Poor’s. Our Moody’s Investors Service rating became effective May 1, 2007, and was an upward revision from our previous Moody’s Investors Service rating of Baa1, which had been in effect since December 2005. Our Standard & Poor’s rating became effective August 20, 2007, and was an upward revision from our previous Standard & Poor’s rating of BBB+, which had been in effect since May 2006. The credit ratings on our short-term debt are P1 with Moody’s Investors Service and A1 with Standard & Poor’s.

BUSINESS ENVIRONMENT AND RESULTS OF OPERATIONS

We operate in approximately 70 countries throughout the world to provide a comprehensive range of discrete and integrated services and products to the energy industry. The majority of our consolidated revenue is derived from the sale of services and products to major, national, and independent oil and gas companies worldwide. We serve the upstream oil and natural gas industry throughout the lifecycle of the reservoir: from locating hydrocarbons and managing geological data, to drilling and formation evaluation, well construction and completion, and optimizing production throughout the life of the field. Our two business segments are the Completion and Production segment and the Drilling and Evaluation segment. The industries we serve are highly competitive with many substantial competitors in each segment. In the first quarter of 2008, based upon the location of the services provided and products sold, 42% of our consolidated revenue was from the United States. In the first quarter of 2007, 45% of our consolidated revenue was from the United States. No other country accounted for more than 10% of our revenue during these periods.

Operations in some countries may be adversely affected by unsettled political conditions, acts of terrorism, civil unrest, force majeure, war or other armed conflict, expropriation or other governmental actions, inflation, exchange control problems, and highly inflationary currencies. We believe the geographic diversification of our business activities reduces the risk that loss of operations in any one country would be material to our consolidated results of operations.

Activity levels within our business segments are significantly impacted by spending on upstream exploration, development, and production programs by major, national, and independent oil and natural gas companies. Also impacting our activity is the status of the global economy, which impacts oil and natural gas consumption.

Some of the more significant barometers of current and future spending levels of oil and natural gas companies are oil and natural gas prices, the world economy, and global stability, which together drive worldwide drilling activity. Our financial performance is significantly affected by oil and natural gas prices and worldwide rig activity, which are summarized in the following tables.

This table shows the average oil and natural gas prices for West Texas Intermediate (WTI) and United Kingdom Brent crude oil, and Henry Hub natural gas:

	Three Months Ended				Year Ended
	March 31				December 31
Average Oil Prices (dollars per barrel)	2008		2007		2007
West Texas Intermediate	$	97.92	$	57.64	$	71.91
United Kingdom Brent		97.04		57.30		72.21

Average United States Natural Gas Prices (dollars per
million British thermal units, or mmBtu)
Henry Hub	$	8.50	$	7.22	$	6.97

The quarterly and yearly average rig counts based on the Baker Hughes Incorporated rig count information were as follows:

	Three Months Ended				Year Ended
	March 31				December 31
Land vs. Offshore	2008		2007		2007
United States:
Land		1,711		1,650		1,694
Offshore		59		83		73
Total		1,770		1,733		1,767
Canada:
Land		506		529		341
Offshore		1		3		3
Total		507		532		344
International (excluding Canada):
Land		763		700		719
Offshore		284		282		287
Total		1,047		982		1,006
Worldwide total		3,324		3,247		3,117
Land total		2,980		2,879		2,754
Offshore total		344		368		363

	Three Months Ended				Year Ended
	March 31				December 31
Oil vs. Natural Gas	2008		2007		2007
United States:
Oil		332		273		297
Natural gas		1,438		1,460		1,470
Total		1,770		1,733		1,767
Canada:
Oil		213		194		128
Natural gas		294		338		216
Total		507		532		344
International (excluding Canada):
Oil		803		763		784
Natural gas		244		219		222
Total		1,047		982		1,006
Worldwide total		3,324		3,247		3,117
Oil total		1,348		1,230		1,209
Natural gas total		1,976		2,017		1,908

Our customers’ cash flows, in many instances, depend upon the revenue they generate from the sale of oil and natural gas. Higher oil and natural gas prices usually translate into higher exploration and production budgets. Higher prices also improve the economic attractiveness of unconventional reservoirs. This promotes additional investment by our customers. The opposite is true for lower oil and natural gas prices.

WTI oil spot prices averaged $72 per barrel in 2007 and are expected to increase to an average of $101 per barrel in 2008, according to the Energy Information Administration (EIA). From mid-December 2007 through March 2008, the WTI crude oil price increased $15 per barrel from an average of $90 per barrel to an average of $105 per barrel as a result of rising world oil consumption and low surplus production capacity. We expect that oil prices will remain at levels sufficient to sustain, and likely grow, our customers’ current levels of spending due to a combination of the following factors:

continued growth in worldwide petroleum demand, despite high oil prices;

projected production growth in non-Organization of Petroleum Exporting Countries (non-OPEC) supplies is not expected to accommodate world wide demand growth;

OPEC’s commitment to control production;

modest increases in OPEC’s current and forecasted production capacity; and

geopolitical tensions in major oil-exporting nations.

According to the International Energy Agency’s (IEA) April 2008 “Oil Market Report,” the outlook for world oil demand remains strong, with Asia, the Middle East, and Latin America accounting for approximately 98% of the expected demand growth in 2008. Excess oil production capacity is expected to remain constrained with OPEC producers’ continuing reluctance to supply additional crude oil to the market. This constraint, along with a strong refined product market, a weaker dollar, and geopolitical tensions, is expected to keep supplies tight. Thus, any unexpected supply disruption or change in demand could lead to fluctuating prices. The IEA forecasts world petroleum demand growth in 2008 to increase 2% over 2007.

North America operations. Volatility in natural gas prices has the potential to impact our customers' drilling and production activities, particularly in North America. During 2007, we experienced a significant decline in activity from 2006 levels in our North America operations, especially in Canada. This slowdown caused us to move equipment and personnel from Canada to other areas in 2007. However, activity in the Canadian market increased in the first quarter of 2008, and there are signs of resurgence in activity after spring break-up. With continued strong natural gas fundamentals, we believe that our customers will reevaluate their North America drilling plans for the second half of the year and that this may lead to volume increases. In April 2008, the EIA noted that the Henry Hub spot price averaged $7.17 per thousand cubic feet (mcf) in 2007 and was projected to increase to an average of $8.59 per mcf in 2008.

It is common practice in the United States oilfield services industry to sell services and products based on a price book and then apply discounts to the price book based upon a variety of factors. The discounts applied typically increase to partially offset price book increases. We experienced increased pricing pressure from our customers in the North American market in 2007 and in the first quarter of 2008, particularly in Canada and in our United States well stimulation operations. However, we have recently seen these pricing pressures begin to level off in certain areas. Pricing declines in the transactional market are easing in areas where activity is increasing and where job and basin complexity favors our differentiated fracturing technologies. Also, prices are beginning to stabilize in our cementing, fluid services, and wireline and perforating services product lines. We are also experiencing cost inflation for fuel and fuel-based supplies and services, which is putting additional downward pressure on operating margins. We are attempting to mitigate these costs by optimizing procurement practices and implementing fuel surcharges to customers, when applicable.

Focus on international growth. Consistent with our strategy to grow our operations outside of North America, we expect to continue to invest capital and increase manufacturing capacity to bring new tools online to serve the high demand for our services. Following is a brief discussion of some of our current initiatives:

in order to continue to supply our customers with leading-edge services and products, we have increased our technology spending and are making our research and development efforts more geographically diverse. To that end, we opened a technology center in India in 2007, and we opened another in Singapore in the first quarter of 2008;

we have expanded our manufacturing capability and capacity to meet the increasing demands for our services and products and to support our planned growth. In 2007 and 2008, we opened four new regional manufacturing facilities in Asia and Latin America. These new centers will enable us to be more responsive to our international customers while, building regional supply networks that support local economies;

as our workforce becomes more global, the need for regional training centers increases. As a result, we have expanded our number of regional training centers to meet this need. We now have 12 training centers worldwide that integrate new workers and advance the technical skills of our workforce; and

part of our growth strategy includes acquisitions that will enhance or augment our current portfolio of products and services, including those with unique technologies or distribution networks in areas where we do not already have large operations. We made such strategic acquisitions in 2007 and are currently evaluating additional opportunities.

Recent contract wins positioning us to grow our international operations over the coming years include:

a contract to manage the drilling and completion of 58 land wells in the southern region of Mexico;

a contract to perform workover and sidetrack services in the United Kingdom;

a contract to provide completion equipment and services, tubing conveyed perforating services and SmartWell® completion technology for numerous oil and natural gas fields on the Norwegian continental shelf. The contracts also allow for the provision of other products and services; and

a three-year contract to provide directional drilling, logging-while-drilling, cementing, logging and perforating, coiled tubing, and stimulation services in support of the offshore portion of the Manifa mega-project in Saudi Arabia.

RESULTS OF OPERATIONS IN 2008 COMPARED TO 2007

Three Months Ended March 31, 2008 Compared with Three Months Ended March 31, 2007

	Three Months Ended
REVENUE:	March 31						Percentage
Millions of dollars	2008		2007		Increase		Change
Completion and Production	$	2,191	$	1,844	$	347		19	%
Drilling and Evaluation		1,838		1,578		260		16
Total revenue	$	4,029	$	3,422	$	607		18	%

By geographic region:
Completion and Production:
North America	$	1,169	$	1,062	$	107	10	%
Latin America		243		166		77	46
Europe/Africa/CIS		433		377		56	15
Middle East/Asia		346		239		107	45
Total		2,191		1,844		347	19
Drilling and Evaluation:
North America		693		610		83	14
Latin America		266		238		28	12
Europe/Africa/CIS		525		406		119	29
Middle East/Asia		354		324		30	9
Total		1,838		1,578		260	16
Total revenue by region:
North America		1,862		1,672		190	11
Latin America		509		404		105	26
Europe/Africa/CIS		958		783		175	22
Middle East/Asia		700		563		137	24

	Three Months Ended
OPERATING INCOME (LOSS):	March 31						Increase			Percentage
Millions of dollars	2008			2007			(Decrease)			Change
Completion and Production	$	529		$	477		$	52			11	%
Drilling and Evaluation		384			362			22			6
Corporate and other		(66	)		(51	)		(15	)		(29	)
Total operating income	$	847		$	788		$	59			7	%

By geographic region:
Completion and Production:
North America	$	317	$	322	$	(5	)	(2	)%
Latin America		66		38		28		74
Europe/Africa/CIS		72		71		1		1
Middle East/Asia		74		46		28		61
Total		529		477		52		11
Drilling and Evaluation:
North America		174		167		7		4
Latin America		41		36		5		14
Europe/Africa/CIS		103		78		25		32
Middle East/Asia		66		81		(15	)	(19	)
Total		384		362		22		6
Total operating income by region
(excluding Corporate and other):
North America		491		489		2		–
Latin America		107		74		33		45
Europe/Africa/CIS		175		149		26		17
Middle East/Asia		140		127		13		10

Note 1 –

All periods presented reflect the new segment structure and the reclassification of certain amounts between the segments/regions and “Corporate and other.”

The increase in consolidated revenue in the first quarter of 2008 compared to the first quarter of 2007 was attributable to higher worldwide activity, particularly in the United States, Europe, and Latin America. International revenue was 58% of consolidated revenue in the first quarter of 2008 and 55% of consolidated revenue in the first quarter of 2007.

The increase in consolidated operating income stemmed from a 45% increase in Latin America and a 14% increase in the eastern hemisphere and was due to increased customer activity and new contracts, primarily in Latin America, Europe, and Asia. Operating income in the first quarter of 2008 was impacted by a $35 million gain on the sale of a joint venture interest in the United States and a $23 million impairment charge related to an oil and gas property in Bangladesh.

Following is a discussion of our results of operations by reportable segment.

Completion and Production increase in revenue compared to the first quarter of 2007 was derived from all regions. Europe/Africa/CIS revenue grew 15% on increased activity from production enhancement services in Europe, largely related to the acquisition of PSL Energy Services Limited. The region also benefited from increased activity in our intelligent well completions joint venture across the region and completion tools sales in Africa. Middle East/Asia revenue improved 45% from increased completion tools sales and deliveries, new contracts for production enhancement services in the region, and increased sales of intelligent well completions in the Middle East. North America revenue grew 10% on increased activity from production enhancement services in the United States and Canada and cementing services activity in the United States, largely driven by increased capacity in the region. Latin America revenue increased 46% driven by improved pricing and new contracts for production enhancement services in Mexico and new cementing services contracts in Mexico. In addition, the region benefited from increased completion tools sales in Brazil and Mexico. International revenue was 50% of total segment revenue in the first quarter of 2008 and 46% of total segment revenue in the first quarter of 2007.

The Completion and Production segment operating income improvement compared to the first quarter of 2007 spanned all regions except North America. Europe/Africa/CIS operating income was essentially flat, despite increased completion tools sales throughout the region. Middle East/Asia operating income grew 61% from improved completion tools sales and deliveries in Asia and the Middle East. North America operating income decreased 2% largely due to a decline in production enhancement services pricing and cost inflation in the United States, partially offset by a $35 million gain on the sale of a joint venture interest. Latin America operating income increased 74% due to increased cementing and production enhancement activity in Mexico and increased completion tools sales in Brazil.

Drilling and Evaluation revenue increase for the first quarter of 2008 compared to the first quarter of 2007 was derived from all four regions. Europe/Africa/CIS revenue improved 29% from increased drilling services activity throughout the region, fluid service contracts in the North Sea and Angola, and increased drill bit sales in Europe. Middle East/Asia revenue grew 9% from increased fluid services throughout the region. The region also benefited from increased drilling services activity and new contracts in the Middle East and Indonesia. North America revenue increased 14% from increased activity in all product service lines, particularly Landmark software sales and consulting services and drilling services in the United States and fluid services throughout the region. Latin America revenue grew 12% on increased activity in wireline and perforating services throughout the region and new drilling services contracts in Colombia and Mexico. International revenue was 67% of total segment revenue in the first quarter of 2008 and 66% of total segment revenue in the first quarter of 2007.

The increase in segment operating income compared to 2007 was led by the Europe/Africa/CIS region, where operating income grew 32% from increased drilling services activity throughout the region, particularly in Russia, the Caspian, and Egypt. In addition, the region benefited from increased Landmark software sales and consulting services in Europe and wireline and perforating services in Europe. Middle East/Asia operating income decreased 19%, primarily due to the oil and gas property impairment in Bangladesh, which was partially offset by increased fluid services in the region, additional drilling activity in the Middle East, and reduced costs for Landmark consulting services in Asia. North America operating income grew 4% from increased Landmark consulting services activity, fluid services, and drill bit sales in the United States. In addition, the region benefited from higher drilling services activity in the Gulf of Mexico. Latin America operating income increased 14% largely from additional wireline and perforating services activity in Mexico and new drilling services contracts in Mexico and Colombia.

Corporate and other expenses were $66 million in the first quarter of 2008 compared to $51 million in the first quarter of 2007. The increase was primarily due to higher legal costs in the first quarter of 2008.

NONOPERATING ITEMS

Interest income decreased $18 million in the first quarter of 2008 compared to the first quarter of 2007 due to lower interest-rate-driven income and divestment of our marketable securities.

Provision for income taxes on continuing operations in the first quarter of 2008 of $238 million resulted in an effective tax rate of 29% compared to an effective tax rate on continuing operations of 33% in the first quarter of 2007. The lower effective tax rate in the first quarter of 2008 was driven by growth in our international operations, which generally are subject to lower income tax rates than our United States operations, as well as from favorable settlements with foreign tax jurisdictions and the ability to recognize additional foreign tax credits that have been substantiated.

Minority interest in net (income) loss of subsidiaries increased $10 million compared to the first three months of 2007 primarily due to increased earnings from our WellDynamics joint venture.

Income from discontinued operations, net of income tax in the first quarter of 2007, primarily consisted of our 81% share of KBR’s results.

ENVIRONMENTAL MATTERS

We are subject to numerous environmental, legal, and regulatory requirements related to our operations worldwide. In the United States, these laws and regulations include, among others:

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.

We do not expect costs related to these remediation requirements to have a material adverse effect on our consolidated financial position or our results of operations. Our accrued liabilities for environmental matters were $70 million as of March 31, 2008 and $72 million as of December 31, 2007. Our total liability related to environmental matters covers numerous properties, including the property in regard to which Dirt, Inc. has brought suit against Bredero-Shaw (a joint venture in which we formerly held a 50% interest that we sold to the other party in the venture, ShawCor Ltd., in 2002), Halliburton Energy Services, Inc., and ShawCor Ltd. See Note 8 to the condensed consolidated financial statements for further information about this matter.

NEW ACCOUNTING STANDARDS

In March 2008, the Financial Accounting Standards Board (FASB) issued Statement of Financial Accounting Standards (SFAS) No. 161, “Disclosure about Derivative Instruments and Hedging Activities – An Amendment of FASB Statement No. 133.” SFAS No. 161 requires more disclosures about an entity’s derivative and hedging activities in order to improve the transparency of financial reporting. SFAS No. 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early application encouraged. This Statement encourages, but does not require, comparative disclosures for earlier periods at initial adoption. We will adopt the provisions of SFAS No. 161 on January 1, 2009, which we do not expect to have a material impact on our consolidated financial statements.

FORWARD-LOOKING INFORMATION

The Private Securities Litigation Reform Act of 1995 provides safe harbor provisions for forward-looking information. Forward-looking information is based on projections and estimates, not historical information. Some statements in this Form 10-Q are forward-looking and use words like “may,” “may not,” “believes,” “do not believe,” “expects,” “do not expect,” “anticipates,” “do not anticipate,” and other expressions. We may also provide oral or written forward-looking information in other materials we release to the public. Forward-looking information involves risk and uncertainties and reflects our best judgment based on current information. Our results of operations can be affected by inaccurate assumptions we make or by known or unknown risks and uncertainties. In addition, other factors may affect the accuracy of our forward-looking information. As a result, no forward-looking information can be guaranteed. Actual events and the results of operations may vary materially.

We do not assume any responsibility to publicly update any of our forward-looking statements regardless of whether factors change as a result of new information, future events, or for any other reason. You should review any additional disclosures we make in our press releases and Forms 10-K, 10-Q, and 8-K filed with or furnished to the SEC. We also suggest that you listen to our quarterly earnings release conference calls with financial analysts.

While it is not possible to identify all factors, we continue to face many risks and uncertainties that could cause actual results to differ from our forward-looking statements and potentially materially and adversely affect our financial condition and results of operations.

The risk factors discussed below update the risk factors previously disclosed in our 2007 annual report on Form 10-K.

RISK FACTORS

Foreign Corrupt Practices Act Investigations

The SEC is conducting a formal investigation into whether improper payments were made to government officials in Nigeria through the use of agents or subcontractors in connection with the construction and subsequent expansion by TSKJ of a multibillion dollar natural gas liquefaction complex and related facilities at Bonny Island in Rivers State, Nigeria. The DOJ is also conducting a related criminal investigation. The SEC has also issued subpoenas seeking information, which we and KBR are furnishing, regarding current and former agents used in connection with multiple projects, including current and prior projects, over the past 20 years located both in and outside of Nigeria in which the Halliburton energy services business, KBR or affiliates, subsidiaries or joint ventures of Halliburton or KBR, are or were participants. In September 2006 and October 2007, the SEC and the DOJ, respectively, each requested that we enter into an agreement to extend the statute of limitations with respect to its investigation. We have entered into tolling agreements with the SEC and the DOJ.

The SEC and the DOJ have been reviewing these matters in light of the requirements of the Foreign Corrupt Practices Act (FCPA). In addition to performing our own investigation, we have been cooperating with the SEC and the DOJ investigations and with other investigations in France, Nigeria, and Switzerland regarding the Bonny Island project. The government of Nigeria gave notice in 2004 to the French magistrate of a civil claim as an injured party in the French investigation. We also believe that the Serious Fraud Office in the United Kingdom is conducting an investigation relating to the Bonny Island project. Our Board of Directors has appointed a committee of independent directors to oversee and direct the FCPA investigations.

Barracuda-Caratinga Arbitration

We also provided indemnification in favor of KBR under the master separation agreement for all out-of-pocket cash costs and expenses (except for legal fees and other expenses of the arbitration so long as KBR controls and directs it), or cash settlements or cash arbitration awards in lieu thereof, KBR may incur after November 20, 2006 as a result of the replacement of certain subsea flowline bolts installed in connection with the Barracuda-Caratinga project. Under the master separation agreement, KBR currently controls the defense, counterclaim, and settlement of the subsea flowline bolts matter. As a condition of our indemnity, for any settlement to be binding upon us, KBR must secure our prior written consent to such settlement’s terms. We have the right to terminate the indemnity in the event KBR enters into any settlement without our prior written consent. See Note 2 to our condensed consolidated financial statements for additional information regarding the KBR indemnification.

Impairment of oil and gas properties

At March 31, 2008, we had interests in oil and gas properties totaling $101 million, net of accumulated depletion, which we account for under the successful efforts method. The majority of this amount is related to one property in Bangladesh in which we have a 25% nonoperating interest. These oil and gas properties are assessed for impairment whenever changes in facts and circumstances indicate that the properties’ carrying amounts may not be recoverable. The expected future cash flows used for impairment reviews and related fair-value calculations are based on judgmental assessments of future production volumes, prices, and costs, considering all available information at the date of review.

A downward trend in estimates of production volumes or prices or an upward trend in costs could result in an impairment of our oil and gas properties, which in turn could have a material and adverse effect on our results of operations.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

We are exposed to financial instrument market risk from changes in foreign currency exchange rates, interest rates, and, to a limited extent, commodity prices. We selectively manage these exposures through the use of derivative instruments to mitigate our market risk from these exposures. The objective of our risk management is to protect our cash flows related to sales or purchases of goods or services from market fluctuations in currency rates. Our use of derivative instruments includes the following types of market risk:

volatility of the currency rates;

time horizon of the derivative instruments;

market cycles; and

the type of derivative instruments used.

We do not use derivative instruments for trading purposes. We do not consider any of these risk management activities to be material.

Item 4. Controls and Procedures

In accordance with the Securities Exchange Act of 1934 Rules 13a-15 and 15d-15, we carried out an evaluation, under the supervision and with the participation of management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of March 31, 2008 to provide reasonable assurance that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. Our disclosure controls and procedures include controls and procedures designed to ensure that information required to be disclosed in reports filed or submitted under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

There has been no change in our internal control over financial reporting that occurred during the three months ended March 31, 2008 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

Information related to various commitments and contingencies is described in “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” in “Forward-Looking Information” and “Risk Factors,” and in Notes 2 and 8 to the condensed consolidated financial statements.

Item 1(a). Risk Factors

Information related to risk factors is described in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” under “Forward-Looking Information” and “Risk Factors.”

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Following is a summary of our repurchases of our common stock during the three-month period ended March 31, 2008.

					Total Number
					of Shares
					Purchased as
	Total Number		Average		Part of Publicly
	of Shares		Price Paid		Announced Plans
Period	Purchased (a)		per Share		or Programs (b)
January 1-31		661,748	$	34.06		500,000
February 1-29		2,738,508	$	37.36		2,732,452
March 1-31		6,465,262	$	37.57		6,416,104
Total		9,865,518	$	37.27		9,648,556

(a)

Of the 9,865,518 shares purchased during the three-month period ended March 31, 2008, 216,962 shares were acquired from employees in connection with the settlement of income tax and related benefit withholding obligations arising from vesting in restricted stock grants. These shares were not part of a publicly announced program to purchase common shares.

(b)

In July 2007, our Board of Directors approved an additional increase to our existing common share repurchase program of up to $2.0 billion, bringing the entire authorization to $5.0 billion. This additional authorization may be used for open market share purchases or to settle the conversion premium on our 3.125% convertible senior notes, should they be redeemed. From the inception of this program, we have repurchased approximately 89 million shares of our common stock for approximately $3.0 billion at an average price of $34.28 per share. These numbers include the repurchases of approximately 10 million shares of our common stock for approximately $360 million at an average price of $37.26 per share during the first quarter of 2008. As of March 31, 2008, approximately $2.0 billion remained available under this program.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Submission of Matters to a Vote of Security Holders

None.

Item 5. Other Information

None.

Item 6. Exhibits

* 31.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act
	of 2002.

* 31.2	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act
	of 2002.

** 32.1	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act
	of 2002.

** 32.2	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act
	of 2002.

*	Filed with this Form 10-Q
**	Furnished with this Form 10-Q

SIGNATURES

As required by the Securities Exchange Act of 1934, the registrant has authorized this report to be signed on behalf of the registrant by the undersigned authorized individuals.

HALLIBURTON COMPANY

/s/ Mark A. McCollum	/s/ Evelyn M. Angelle
Mark A. McCollum	Evelyn M. Angelle
Executive Vice President and	Vice President, Corporate Controller, and
Chief Financial Officer	Principal Accounting Officer

Date: April 25, 2008