Edgar Filing: KBR, INC.

form10q.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 June 30, 2010

o Transition Report Pursuant to Section 13 or 15(d)

of the Securities Exchange Act of 1934

For the transition period from _____ to _____

Commission File Number 1-33146

KBR, Inc.

(a Delaware Corporation)

20-4536774

601 Jefferson Street

Suite 3400

Houston, Texas 77002

(Address of Principal Executive Offices)

Telephone Number – Area Code (713) 753-3011

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 at least the past 90 days.

Yes x No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes x No o

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. (Check one):

Large accelerated filer x		Accelerated filer o

Non-accelerated filer o (Do not check if a smaller reporting company)		Smaller reporting company o

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

Yes o No x

As of July 28, 2010, 156,272,078 shares of KBR, Inc. common stock, $0.001 par value per share, were outstanding.

KBR, Inc.

Index

		Page No.
PART I.	FINANCIAL INFORMATION	4

Item 1.	Financial Statements	4

	Condensed Consolidated Statements of Income	4
	Condensed Consolidated Balance Sheets	5
	Condensed Consolidated Statements of Comprehensive Income	6
	Condensed Consolidated Statements of Cash Flows	7
	Notes to Condensed Consolidated Financial Statements	8

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	29

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	50

Item 4.	Controls and Procedures	50

PART II.	OTHER INFORMATION	50

Item 1.	Legal Proceedings	50

Item 1A.	Risk Factors	50

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	51

Item 3.	Defaults Upon Senior Securities	51

Item 4.	(Removed and Reserved)	51

Item 5.	Other Information	51

Item 6.	Exhibits	52

SIGNATURES		53

Index

Forward-Looking and Cautionary Statements

This report contains certain statements that are, or may be deemed to be, “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The Private Securities Litigation Reform Act of 1995 provides safe harbor provisions for forward looking information. Some of the statements contained in this quarterly report are forward-looking statements. All statements other than statements of historical fact are, or may be deemed to be, forward-looking statements. The words “believe,” “may,” “estimate,” “continue,” “anticipate,” “intend,” “plan,” “expect” and similar expressions are intended to identify forward-looking statements. Forward-looking statements include information concerning our possible or assumed future financial performance and results of operations.

We have based these statements on our assumptions and analyses in light of our experience and perception of historical trends, current conditions, expected future developments and other factors we believe are appropriate in the circumstances. Forward-looking statements by their nature involve substantial risks and uncertainties that could significantly affect expected results, and actual future results could differ materially from those described in such statements. While it is not possible to identify all factors, factors that could cause actual future results to differ materially include the risks and uncertainties disclosed in our 2009 Annual Report on Form 10-K contained in Part I under “Risk Factors”.

Many of these factors are beyond our ability to control or predict. Any of these factors, or a combination of these factors, could materially and adversely affect our future financial condition or results of operations and the ultimate accuracy of the forward-looking statements. These forward-looking statements are not guarantees of our future performance, and our actual results and future developments may differ materially and adversely from those projected in the forward-looking statements. We caution against putting undue reliance on forward-looking statements or projecting any future results based on such statements or on present or prior earnings levels. In addition, each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to publicly update or revise any forward-looking statement.

Index

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

KBR, Inc.

Condensed Consolidated Statements of Income

(In millions, except for per share data)

(Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2010			2009			2010			2009
Revenue:
Services	$	2,610		$	3,075		$	5,226		$	6,254
Equity in earnings of unconsolidated affiliates, net		61			26			76			47
Total revenue		2,671			3,101			5,302			6,301
Operating costs and expenses:
Cost of services		2,415			2,910			4,898			5,919
General and administrative		55			54			104			103
Loss (gain) on disposition of assets, net		2			—			2			(2	)
Total operating costs and expenses		2,472			2,964			5,004			6,020
Operating income		199			137			298			281
Interest income (expense), net		(5	)		—			(9	)		1
Foreign currency gains (losses), net		(3	)		(4	)		(5	)		1
Other non-operating expense		—			(1	)		—			(1	)
Income before income taxes and noncontrolling interests		191			132			284			282
Provision for income taxes		(69	)		(49	)		(103	)		(104	)
Net Income		122			83			181			178
Less: Net income attributable to noncontrolling interests		(16	)		(16	)		(29	)		(34	)
Net income attributable to KBR	$	106		$	67		$	152		$	144

Net income attributable to KBR per share:
Basic	$	0.66		$	0.42		$	0.94		$	0.90
Diluted	$	0.66		$	0.42		$	0.94		$	0.89

Basic weighted average common shares outstanding		160			160			160			160
Diluted weighted average common shares outstanding		161			161			161			161

Cash dividends declared per share	$	0.05		$	0.05		$	0.10		$	0.10

See accompanying notes to condensed consolidated financial statements.

Index

KBR, Inc.

Condensed Consolidated Balance Sheets

(In millions except share data)

(Unaudited)

	June 30,			December 31,
	2010				2009
Assets
Current assets:
Cash and equivalents	$	1,235			$	941
Receivables:
Accounts receivable, net of allowance for bad debts of $29 and $26		1,419				1,243
Unbilled receivables on uncompleted contracts		529				657
Total receivables		1,948				1,900
Deferred income taxes		216				192
Other current assets		404				608
Total current assets		3,803				3,641
Property, plant, and equipment, net of accumulated depreciation of $299 and $264 (including $80 and $0, net, owned by a variable interest entity – see Note 11)		335				251
Goodwill		696				691
Intangible assets, net		77				58
Equity in and advances to related companies		226				164
Noncurrent deferred income taxes		103				120
Noncurrent unbilled receivables on uncompleted contracts		320				321
Other assets		87				81
Total assets	$	5,647			$	5,327
Liabilities and Shareholders’ Equity
Current liabilities:
Accounts payable	$	977			$	1,045
Due to former parent, net		49				53
Advance billings on uncompleted contracts		621				407
Reserve for estimated losses on uncompleted contracts		31				40
Employee compensation and benefits		239				191
Current non-recourse project-finance debt of a variable interest entity (See Note 11)		8				—
Other current liabilities		492				552
Current liabilities related to discontinued operations, net		2				3
Total current liabilities		2,419				2,291
Noncurrent employee compensation and benefits		431				469
Noncurrent non-recourse project-finance debt of a variable interest entity (See Note 11)		93				—
Other noncurrent liabilities		126				106
Noncurrent income tax payable		78				43
Noncurrent deferred tax liability		116				122
Total liabilities		3,263				3,031

KBR Shareholders’ equity:
Preferred stock, $0.001 par value, 50,000,000 shares authorized, 0 shares issued and outstanding		—				—
Common stock, $0.001 par value, 300,000,000 shares authorized, 170,963,437 and 170,686,531 shares issued, and 158,149,618 and 160,363,830 shares outstanding		—				—
Paid-in capital in excess of par		2,104				2,103
Accumulated other comprehensive loss		(439	)			(444	)
Retained earnings		998				854
Treasury stock, 12,813,819 shares and 10,322,701 shares, at cost		(281	)			(225	)
Total KBR shareholders’ equity		2,382				2,288
Noncontrolling interests		2				8
Total shareholders’ equity		2,384				2,296
Total liabilities and shareholders’ equity	$	5,647			$	5,327

See accompanying notes to condensed consolidated financial statements.

Index

KBR, Inc.

Condensed Consolidated Statements of Comprehensive Income

(In millions)

(Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2010			2009			2010			2009
Net income	$	122		$	83		$	181		$	178
Other comprehensive income (loss), net of tax benefit (provision):
Net cumulative translation adjustments		(8	)		14			(6	)		10
Pension liability adjustments		3			4			6			10
Net unrealized gain (loss) on derivatives		1			1			4			(2	)
Total other comprehensive income (loss), net of tax		(4	)		19			4			18
Comprehensive income		118			102			185			196
Less: Comprehensive income attributable to noncontrolling interests		(15	)		(21	)		(28	)		(41	)
Comprehensive income attributable to KBR	$	103		$	81		$	157		$	155

See accompanying notes to condensed consolidated financial statements.

Index

KBR, Inc.

Condensed Consolidated Statements of Cash Flows

(In millions)

(Unaudited)

	Six Months Ended
	June 30,
	2010			2009
Cash flows from operating activities:
Net income	$	181		$	178
Adjustments to reconcile net income to net cash provided by (used in) operations:
Depreciation and amortization		29			28
Equity in earnings of unconsolidated affiliates		(76	)		(47	)
Deferred income taxes		(20	)		(33	)
Other		20			2
Changes in operating assets and liabilities:
Receivables		(183	)		(65	)
Unbilled receivables on uncompleted contracts		95			70
Accounts payable		(65	)		(125	)
Advanced billings on uncompleted contracts		261			(79	)
Accrued employee compensation and benefits		50			4
Reserve for loss on uncompleted contracts		(9	)		(16	)
Collection (repayment) of advances from (to) unconsolidated affiliates, net		(4	)		3
Distribution of earnings from unconsolidated affiliates		29			17
Other assets		32			(1	)
Other liabilities		92			56
Total cash flows provided by (used in) operating activities		432			(8	)
Cash flows from investing activities:
Capital expenditures		(19	)		(16	)
Investment in equity method joint venture		(7	)		—
Investment in licensing arrangement		(20	)		—
Acquisition of business, net of cash acquired		(10	)		—
Other investing activities		—			3
Total cash flows used in investing activities		(56	)		(13	)
Cash flows from financing activities:
Payments to reacquire common stock		(58	)		(21	)
Payments of dividends to shareholders		(16	)		(16	)
Distributions to noncontrolling shareholders, net		(30	)		(9	)
Net proceeds from issuance of stock		1			—
Payments on long-term borrowings		(4	)		—
Return (funding) of cash collateral on letters of credit, net		24			(13	)
Total cash flows used in financing activities		(83	)		(59	)
Effect of exchange rate changes on cash		(21	)		12
Increase (decrease) in cash and equivalents		272			(68	)
Cash increase due to consolidation of a variable interest entity		22			—
Cash and equivalents at beginning of period		941			1,145
Cash and equivalents at end of period	$	1,235		$	1,077

Noncash operating activities
Other assets (see Note 7)	$	83		$	322
Other liabilities (see Note 7)	$	(83	)	$	(322	)
Noncash investing activities
Purchase of computer software		(19	)		—
Noncash financing activities
Dividends declared or payable	$	8		$	8

See accompanying notes to condensed consolidated financial statements.

Index

Note 1. Description of Business and Basis of Presentation

KBR, Inc. and its subsidiaries (collectively, “KBR”) is a global engineering, construction and services company supporting the energy, petrochemicals, government services, industrial and civil infrastructure sectors. We offer a wide range of services through four business segments: Infrastructure, Government and Power (“IGP”), Hydrocarbons, Services and Ventures. See Note 4 for financial information about our reportable business segments.

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with the rules of the United States Securities and Exchange Commission (“SEC”) for interim financial statements and do not include all annual disclosures required by accounting principles generally accepted in the United States. These condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2009 filed with the SEC. We believe that the presentation and disclosures herein are adequate to make the information not misleading, and the condensed consolidated financial statements reflect all normal adjustments that management considers necessary for a fair presentation of our consolidated results of operations, financial position and cash flows. Operating results for interim periods are not necessarily indicative of results to be expected for the full fiscal year 2010 or any other future periods.

The preparation of our condensed consolidated financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the balance sheet dates and the reported amounts of revenue and costs during the reporting periods. Actual results could differ materially from those estimates. On an ongoing basis, we review our estimates based on information currently available, and changes in facts and circumstances may cause us to revise these estimates.

Our condensed consolidated financial statements include the accounts of majority-owned, controlled subsidiaries and variable interest entities where we are the primary beneficiary. The equity method is used to account for investments in affiliates in which we have the ability to exert significant influence over the affiliates’ operating and financial policies. The cost method is used when we do not have the ability to exert significant influence. All material intercompany accounts and transactions are eliminated.

Effective January 1, 2010, we elected to change our annual goodwill impairment testing to the fourth quarter of every year based on carrying values of our reporting units as of October 1 from our previous method of using our reporting unit carrying values as of September 30. An annual goodwill impairment test date of October 1 better aligns with our annual budgetary process which is completed during the fourth quarter of each year. In addition, performing our annual goodwill impairment test during the fourth quarter will allow for a more thorough consideration of the valuations of our reporting units subsequent to the completion of our annual budgetary process but prior to our financial year end reporting date. As a result of this accounting change, there are no required adjustments to any of the financial statement line items in the accompanying financial statements.

Note 2. Income per Share

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

	Three Months Ended				Six Months Ended
	June 30,				June 30,
Millions of shares	2010		2009		2010		2009
Basic weighted average common shares outstanding		160		160		160		160
Dilutive effect of:
Stock options and restricted shares		1		1		1		1
Diluted weighted average common shares outstanding		161		161		161		161

For purposes of applying the two-class method in computing earnings per share, net earnings allocable to participating securities was approximately $1 million for the three and six months ended June 30, 2010, and for the six months ended June 30, 2009. Net earnings allocable to participating securities did not have a material impact on earnings per share for the three months ended June 30, 2009. The diluted earnings per share calculation did not include 1.0 million and 1.4 million anti-dilutive weighted average shares for the three and six months ended June 30, 2010, respectively. The diluted earnings per share calculation did not include 2.8 million and 2.6 million anti-dilutive weighted average shares for the three and six months ended June 30, 2009, respectively.

Index

Note 3. Percentage-of-Completion Contracts

Unapproved claims

The amounts of unapproved claims and change orders included in determining the profit or loss on contracts and recorded in current and non-current unbilled receivables on uncompleted contracts are as follows:

	June 30,		December 31,
Millions of dollars	2010		2009
Probable unapproved claims	$	31	$	33
Probable unapproved change orders		12		61
Probable unapproved change orders related to unconsolidated subsidiaries		4		2

As of June 30, 2010, the probable unapproved claims related to two completed projects. See Note 6 for a discussion of U.S. government contract claims, which are not included in the table above.

Included in the table above are amounts that will likely not be settled within one year totaling $18 million at June 30, 2010, and $20 million at December 31, 2009, which are reflected as a non-current asset in “Noncurrent unbilled receivables on uncompleted contracts” on the condensed consolidated balance sheets. Other probable unapproved claims and change orders that we believe will be settled within one year, have been recorded as a current asset in “Unbilled receivables on uncompleted contracts” on the condensed consolidated balance sheets.

PEMEX Arbitration. In 1997 and 1998 we entered into three contracts with PEMEX, the project owner, to build offshore platforms, pipelines and related structures in the Bay of Campeche offshore Mexico. The three contracts were known as Engineering, Procurement and Construction (“EPC”) 1, EPC 22 and EPC 28. All three projects encountered significant schedule delays and increased costs due to problems with design work, late delivery and defects in equipment, increases in scope and other changes. PEMEX took possession of the offshore facilities of EPC 1 in March 2004 after having achieved oil production but prior to our completion of our scope of work pursuant to the contract.

We filed for arbitration with the International Chamber of Commerce (“ICC”) in 2004 claiming recovery of damages of $323 million for EPC 1 and PEMEX subsequently filed counterclaims totaling $157 million. The EPC 1 arbitration hearings were held in November 2007. In December 2009, the ICC ruled in our favor and we were awarded a total of approximately $351 million including legal and administrative recovery fees as well as interest. PEMEX was awarded approximately $6 million on counterclaims, plus interest on a portion of that sum. The amount of the award exceeded the book value of our claim receivable resulting in our recognition of a $183 million of operating income and $117 million of net income in the fourth quarter of 2009. The arbitration award is legally binding and we have filed a proceeding in U.S. Federal Court to recognize the award pursuant to which hearings were held in July 2010. PEMEX has attempted to challenge jurisdiction of the U.S. Federal Court and to nullify the award in Mexican court. In the second quarter of 2010, the Mexican trial court rejected PEMEX’s nullification petition. We will respond to further efforts by PEMEX to nullify our award as may be required. We believe the timing of the collection of the award is uncertain and therefore, we have classified the amount due from PEMEX for EPC 1 as a long term receivable included in “Noncurrent unbilled receivable on long term contracts” as of June 30, 2010.

In Amenas Project. We own a 50% interest in an unconsolidated joint venture which began construction of a gas processing facility in Algeria in early 2003 known as the In Amenas project which was completed in 2006. Five months after the contract was awarded in 2003, the client requested the joint venture to relocate to a new construction site as a result of soil conditions discovered at the original site. The joint venture subsequently filed for arbitration with the ICC claiming recovery of $129 million. During the first quarter of 2009, we received a ruling on the claim brought forth by the joint venture against the client. Although the joint venture was awarded recovery of relocation costs thereon of approximately $33 million, it did not prevail on the claim for extension of time for filing of liquidated damages and other damage claims. As a result of the ruling, we recognized a loss of approximately $15 million during the first quarter of 2009 which is recorded in “Equity in earnings of unconsolidated affiliates, net” in our Condensed Consolidated Statements of Income. The loss represents the difference in the amount awarded by the ICC and the amount initially recorded in 2006.

Index

Note 4. Business Segment Information

We provide a wide range of services, but the management of our business is heavily focused on major projects within each of our reportable segments. At any given time, a relatively few number of projects and joint ventures represent a substantial part of our operations. Our equity in earnings and losses of unconsolidated affiliates that are accounted for using the equity method of accounting is included in revenue of the applicable segment.

The table below presents information on our reportable business segments.

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Millions of dollars	2010			2009			2010			2009
Revenue: (a)
Hydrocarbons	$	1,004		$	933		$	1,926		$	1,817
Infrastructure, Government and Power		1,197			1,658			2,471			3,481
Services		452			498			867			973
Other		18			12			38			30
Total revenue	$	2,671		$	3,101		$	5,302		$	6,301

Operating segment income: (a)
Hydrocarbons	$	116		$	83		$	192		$	160
Infrastructure, Government and Power		105			86			151			171
Services		25			24			46			43
Other		6			1			15			12
Operating segment income		252			194			404			386

Unallocated amounts:
Labor cost absorption (b)		4			(3	)		—			(2	)
Corporate loss on disposition of assets		(2	)		—			(2	)		—
Corporate general and administrative		(55	)		(54	)		(104	)		(103	)
Total operating income	$	199		$	137		$	298		$	281

____________________

(a)

Operating segment performance is evaluated by our chief operating decision maker using operating segment income which is defined as operating segment revenue less the cost of services and segment overhead directly attributable to the operating segment. Intersegment revenues are eliminated from operating segment revenues. Operating segment income excludes certain cost of services directly attributable to the operating segment that is managed and reported at the corporate level, and corporate general and administrative expenses. We believe this is the most accurate measure of the ongoing profitability of our operating segments.

(b)	Labor cost absorption represents costs incurred by our central service labor and resource groups (above)/under the amounts charged to the operating segments.

Index

Balance Sheet Information by Operating Segment

	June 30,
Millions of dollars	2010

Total assets:
Hydrocarbons	$	2,131
Infrastructure, Government and Power		2,809
Services		581
Other		126
Total assets	$	5,647

Goodwill:
Hydrocarbons	$	249
Infrastructure, Government and Power		149
Services		286
Other		12
Total	$	696

Equity in/advances to related companies:
Hydrocarbons	$	48
Infrastructure, Government and Power		10
Services		40
Other		128
Total	$	226

Note 5. Committed and Restricted Cash

Cash and equivalents include cash related to contracts in progress as well as cash held by our joint ventures that we consolidate for accounting purposes. Joint venture cash balances are limited to joint venture activities and are not available for other projects, general cash needs, or distribution to us without approval of the board of directors of the respective joint ventures. Cash held by our joint ventures that we consolidate for accounting purposes totaled approximately $267 million at June 30, 2010 and $236 million at December 31, 2009. We expect to use the cash on these projects to pay project costs.

Included in “Other current assets” and “Other assets” at June 30, 2010 is restricted cash in the amounts of $14 million and $9 million, respectively. Restricted cash primarily consists of amounts held in deposit with certain banks to collateralize standby letters of credit.

Note 6. United States Government Contract Work

We provide substantial work under our government contracts to the United States Department of Defense and other governmental agencies. These contracts include our worldwide United States Army logistics contracts, known as LogCAP, and the U.S. Army Europe (“USAREUR”) contract.

Given the demands of working in Iraq and elsewhere for the United States government, as discussed further below, we have disagreements and have experienced performance issues with the various government customers for which we work. When performance issues arise under any of our government contracts, the government retains the right to pursue remedies, which could include threatened termination or termination, under any affected contract. If any contract were so terminated, we may not receive award fees under the affected contract, and our ability to secure future contracts could be adversely affected, although we would receive payment for amounts owed for our allowable costs under cost-reimbursable contracts. Other remedies that could be sought by our government customers for any improper activities or performance issues include sanctions such as forfeiture of profits, suspension of payments, fines, and suspensions or debarment from doing business with the government. Further, the negative publicity that could arise from disagreements with our customers or sanctions as a result thereof could have an adverse effect on our reputation in the industry, reduce our ability to compete for new contracts, and may also have a material adverse effect on our business, financial condition, results of operations, and cash flow.

Index

We have experienced and expect to be a party to various claims against us by employees, third parties, soldiers, subcontractors and others that have arisen out of our work in Iraq such as claims for wrongful termination, assaults against employees, personal injury claims by third parties and army personnel, and subcontractor claims. While we believe we conduct our operations safely, the environments in which we operate often lead to these types of claims. We believe the vast majority of these types of claims are governed by the Defense Base Act or precluded by other defenses. We have a dispute resolution program under which most employment claims are subject to binding arbitration. However, as a result of amendments to the Department of Defense Appropriations Act of 2010, certain types of employee claims cannot be compelled to binding arbitration. An unfavorable resolution or disposition of these matters could have a material adverse effect on our business, results of operations, financial condition and cash flow.

Award Fees

In accordance with the provisions of the LogCAP III contract, we earn profits on our services rendered based on a combination of a fixed fee plus award fees granted by our customer. Both fees are measured as a percentage rate applied to estimated and negotiated costs. The LogCAP III customer is contractually obligated to periodically convene Award-Fee Boards, which are comprised of individuals who have been designated to assist the Award Fee Determining Official (“AFDO”) in making award fee determinations. Award fees are based on evaluations of our performance using criteria set forth in the contract, which include non-binding monthly evaluations made by our customers in the field of operations. Although these criteria have historically been used by the Award-Fee Boards in reaching their recommendations, the amounts of award fees are determined at the sole discretion of the AFDO.

On February 19, 2010, KBR was notified by the AFDO that a determination had been made regarding the Company’s performance for the period January 2008 to April 2008 in Iraq. The notice stated that based on information received from various Department of Defense individuals and organizations after the date of the evaluation board held in June 2008, the AFDO made a unilateral decision to grant no award fees for the period of performance from January 2008 to April 2008.

As a result of the AFDO’s adverse determination, in the fourth quarter of 2009, we reversed award fees that had previously been estimated as earned and recognized as revenue. Until we are able to reliably estimate fees to be awarded in the future, we will recognize award fees on the LogCAP III contract in the period they are awarded. In May 2010, we received an award fee of approximately $60 million representing approximately 47% of the available award fee pool for the period of performance from May 2008 through August 2009 which we recorded as an increase to revenue in the second quarter of 2010. We expect to be notified in the second half of 2010 of the results of the Award Fee Evaluation Boards held in late June 2010 for the periods of performance from September 2009 through February 2010 on task orders in Iraq and from September 2009 through May 2010 on task orders in Afghanistan. If our next award fee letter has performance scores and award rates at levels for which we receive an award, our revenues and earnings will increase accordingly.

Prior to the fourth quarter of 2009, we recognized award fees on the LogCAP III contract using an estimated accrual of the amounts to be awarded. Once task orders underlying the work are definitized and award fees are granted, we adjust our estimate of award fees to the actual amounts earned. We used 72% as our accrual rate through the third quarter of 2009.

DCAA Audit Issues

The negotiation, administration and settlement of our contracts with the U.S. Government, consisting primarily of Department of Defense contracts, are subject to audit by the Defense Contract Audit Agency (“DCAA”), which serves in an advisory role to government administrative contracting officers who administer our contracts. The scope of these audits include, among other things, the allowability, allocability and reasonableness of incurred costs, approval of annual overhead rates, compliance with the Federal Acquisition Regulation (“FAR”), compliance with certain unique contract clauses, and audits of certain aspects of our internal control systems. Issues identified during these audits are typically discussed and reviewed with us, and certain matters are included in audit reports issued by the DCAA, with its recommendations to our customer’s administrative contracting officer. We attempt to resolve all issues identified in audit reports by working directly with the DCAA and the administrative contracting officer. When agreement cannot be reached, DCAA may issue a Form 1, “Notice of Contract Costs Suspended and/or Disapproved,” which recommends withholding the previously paid amounts or it may issue an advisory report to the administrative contracting officer. KBR is permitted to respond to these documents and provide additional support. The Company has open Form 1’s from DCAA recommending suspension of payments totaling approximately $356 million associated with our contract costs incurred in prior years, of which approximately $165 million has been withheld from our current billings. As a consequence, for certain of these matters, we have withheld approximately $124 million from our subcontractors under the payment terms of those contracts. In addition, we have outstanding demand letters received from our customer requesting that we remit a total of $135 million of disapproved costs for which we currently do not intend to pay. We continue to work with our administrative contracting officers, the DCAA and our subcontractors to resolve these issues. However, for certain of these matters, we have filed claims with the Armed Services Board of Contract Appeals or the United States Court of Federal Claims.

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We self-disallow costs that are expressly not allowable or allocable to government contracts per the relevant regulations. Revenue recorded for government contract work is reduced for our estimate of potentially refundable costs related to issues that may be categorized as disputed or unallowable as a result of cost overruns or the audit process. Our estimates of potentially unallowable costs are based upon, among other things, our internal analysis of the facts and circumstances, terms of the contracts and the applicable provisions of the FAR, quality of supporting documentation for costs incurred, and subcontract terms as applicable. From time to time, we engage outside counsel to advise us on certain matters in determining whether certain costs are allowable. We also review our analysis and findings with the DCMA’s Administrative Contracting Officer (“ACO”) as appropriate. In some cases, we may not reach agreement with the DCAA or the ACO regarding potentially unallowable costs which may result in our filing of claims in various courts. We only include amounts in revenue related to disputed and potentially unallowable costs when we determine it is probable that such costs will result in revenue. We generally do not recognize additional revenue for disputed or potentially unallowable costs for which revenue has been previously reduced until we reach agreement with the DCAA and/or the ACO that such costs are allowable.

Certain issues raised as a result of contract audits and other investigations are discussed below.

Private Security. In February 2007, we received a Form 1 notice from the Department of the Army informing us of their intent to adjust payments under the LogCAP III contract associated with the cost incurred for the years 2003 through 2006 by certain of our subcontractors to provide security to their employees. Based on that notice, the Army withheld its initial assessment of $20 million. The Army based its initial assessment on one subcontract wherein, based on communications with the subcontractor, the Army estimated 6% of the total subcontract cost related to the private security costs. The Army previously indicated that not all task orders and subcontracts have been reviewed and that they may make additional adjustments. In August 2009, we received a Form 1 notice from the DCAA disapproving an additional $83 million of costs incurred by us and our subcontractors to provide security during the same periods. Since that time, the Army withheld an additional $24 million in payments from us bringing the total payments withheld to approximately $44 million as of June 30, 2010 out of the Form 1 notices issued to date of $103 million.

The Army indicated that they believe our LogCAP III contract prohibits us and our subcontractors from billing costs of privately acquired security. We believe that, while the LogCAP III contract anticipates that the Army will provide force protection to KBR employees, it does not prohibit us or any of our subcontractors from using private security services to provide force protection to KBR or subcontractor personnel. In addition, a significant portion of our subcontracts are competitively bid fixed price subcontracts. As a result, we do not receive details of the subcontractors’ cost estimate nor are we legally entitled to it. Further, we have not paid our subcontractors any additional compensation for security services. Accordingly, we believe that we are entitled to reimbursement by the Army for the cost of services provided by us or our subcontractors, even if they incurred costs for private force protection services. Therefore, we believe that the Army’s position that such costs are unallowable and that they are entitled to withhold amounts incurred for such costs is wrong as a matter of law.

In 2007, we provided at the Army's request information that addresses the use of armed security either directly or indirectly charged to LogCAP III. In October 2007, we filed a claim to recover the original $20 million that was withheld which was deemed denied as a result of no response from the contracting officer. To date, we have filed appeals to the Armed Services Board of Contract Appeals (“ASBCA”) to recover $44 million of the amounts withheld from us. We believe these sums were properly billed under our contract with the Army. At this time, we believe the likelihood that a loss related to this matter has been incurred is remote. We have not adjusted our revenues or accrued any amounts related to this matter. This matter is also the subject of a separate claim filed by the Department of Justice (“DOJ”) for alleged violation of the False Claims Act as discussed further below under the heading “Investigations, Qui Tams and Litigation.” Our appeal to the ASBCA is effectively stayed pending the resolution of the separate claim filed by the DOJ.

Containers. In June 2005, the DCAA recommended withholding certain costs associated with providing containerized housing for soldiers and supporting civilian personnel in Iraq. The Defense Contract Management Agency (“DCMA”) recommended that the costs be withheld pending receipt of additional explanation or documentation to support the subcontract costs. We have not received a final determination by the DCMA and continue to provide information as requested by the DCMA. As of June 30, 2010, approximately $30 million of costs have been suspended under Form 1 notices and withheld from us by our customer related to this matter of which $28 million has been withheld by us from our subcontractors. In April 2008, we filed a counterclaim in arbitration against one of our LogCAP III subcontractors, First Kuwaiti Trading Company, to recover approximately $51 million paid to the subcontractor for containerized housing as further described under the caption First Kuwaiti Trading Company arbitration below. We will continue working with the government and our subcontractors to resolve the remaining amounts. We believe that the costs incurred associated with providing containerized housing are reasonable and we intend to vigorously defend ourselves in this matter and we do not believe that we face a risk of significant loss from any disallowance of these costs in excess of the amounts we have withheld from subcontractors and the loss accruals we have recorded. At this time, the likelihood that a loss in excess of the amount accrued for this matter is remote.

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Dining facilities. In 2006, the DCAA raised questions regarding our billings and price reasonableness of costs related to dining facilities in Iraq. We responded to the DCMA that our costs are reasonable. Since 2007, the DCAA has sent Form 1 notices totaling $187 million suspending costs related to these dining facilities until such time we provide documentation to support the price reasonableness of the rates negotiated with our subcontractor and demonstrate that the amounts billed were in accordance with the contract terms. We believe the prices obtained for these services were reasonable and intend to vigorously defend ourselves on this matter. We filed claims in the U.S. Court of Federal Claims to recover $57 million of the $77 million withheld from us by the customer. With respect to questions raised regarding billing in accordance with contract terms, as of June 30, 2010, we believe it is reasonably possible that we could incur losses in excess of the amount accrued for possible subcontractor costs billed to the customer that were possibly not in accordance with contract terms. However, we are unable to estimate an amount of possible loss or range of possible loss in excess of the amount accrued related to any costs billed to the customer that were not in accordance with the contract terms. We believe the prices obtained for these services were reasonable, we intend to vigorously defend ourselves in this matter and we do not believe we face a risk of significant loss from any disallowance of these costs in excess of amounts withheld from subcontractors. As of June 30, 2010, we had withheld $87 million in payments from our subcontractors pending the resolution of these matters with our customer.

Additionally, one of our subcontractors, Tamimi, has filed for arbitration to recover approximately $35 million for payments we have withheld from them pending the resolution of the Form 1 notices with our customer. Should we not reach a favorable resolution of the Form 1 notices, the subcontract terms allow us to offset the amounts owed to our subcontractor to the extent we do not receive payment from our customer related to these questioned costs.

Transportation costs. The DCAA, in performing its audit activities under the LogCAP III contract, raised a question about our compliance with the provisions of the Fly America Act. Subject to certain exceptions, the Fly America Act requires Federal employees and others performing U.S. Government-financed foreign air travel to travel by U.S. flag air carriers. There are times when we transported personnel in connection with our services for the U.S. military where we may not have been in compliance with the Fly America Act and its interpretations through the Federal Acquisition Regulations and the Comptroller General. As of June 30, 2010, we have accrued an estimate of the cost incurred for these potentially non-compliant flights with a corresponding reduction to revenue. The DCAA may consider additional flights to be noncompliant resulting in potential larger amounts of disallowed costs than the amount we have accrued. At this time, we cannot estimate a range of reasonably possible losses that may have been incurred, if any, in excess of the amount accrued. We will continue to work with our customer to resolve this matter.

Construction services. In the third quarter of 2009, we received Form 1 notices from the DCAA disapproving approximately $28 million in costs related to work performed under our CONCAP III contract with the U.S. Navy to provide emergency construction services primarily to Government facilities damaged by Hurricanes Katrina and Wilma. The DCAA claims the costs billed to the U.S. Navy primarily related to subcontract costs that were either inappropriately bid, included unallowable profit markup or were unreasonable. In April 2010, we met with the U.S. Navy in an attempt to settle the potentially unallowable costs. As a result of the meeting, approximately $7 million of the potentially unallowable costs were deemed allowable by our customer and less than $1 million was deemed unallowable. Settlement of the remaining $20 million is pending further discussions with the customer regarding the applicable provisions of the FAR and interpretations thereof, as well as providing additional supporting documentation to the customer. As of June 30, 2010, the U.S. Navy has withheld approximately $10 million from us. We believe we undertook adequate and reasonable steps to ensure that proper bidding procedures were followed and the amounts billed to the customer were reasonable and not in violation of the FAR. As of June 30, 2010, we have accrued our estimate of probable loss related to this matter; however, it is reasonably possible we could incur additional losses.

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Investigations, Qui Tams and Litigation

The following matters relate to ongoing litigation or investigations involving U.S. government contracts.

McBride Qui Tam suit. In September 2006, we became aware of a qui tam action filed against us by a former employee alleging various wrongdoings in the form of overbillings of our customer on the LogCAP III contract. This case was originally filed pending the government’s decision whether or not to participate in the suit. In June 2006, the government formally declined to participate. The principal allegations are that our compensation for the provision of Morale, Welfare and Recreation (“MWR”) facilities under LogCAP III is based on the volume of usage of those facilities and that we deliberately overstated that usage. In accordance with the contract, we charged our customer based on actual cost, not based on the number of users. It was also alleged that, during the period from November 2004 into mid-December 2004, we continued to bill the customer for lunches, although the dining facility was closed and not serving lunches. There are also allegations regarding housing containers and our provision of services to our employees and contractors. On July 5, 2007, the court granted our motion to dismiss the qui tam claims and to compel arbitration of employment claims including a claim that the plaintiff was unlawfully discharged. The majority of the plaintiff’s claims were dismissed but the plaintiff was allowed to pursue limited claims pending discovery and future motions. Substantially all employment claims were sent to arbitration under the Company’s dispute resolution program and were subsequently resolved in our favor. In January 2009, the relator filed an amended complaint which is nearing completion of the discovery process. Trial for this matter is expected in early 2011. We believe the relator’s claim is without merit and that the likelihood that a loss has been incurred is remote. As of June 30, 2010, no amounts have been accrued.

Godfrey Qui Tam suit. In December 2005, we became aware of a qui tam action filed against us and several of our subcontractors by a former employee alleging that we violated the False Claims Act by submitting overcharges to the government for dining facility services provided in Iraq under the LogCAP III contract. As required by the False Claims Act, the lawsuit was filed under seal to permit the government to investigate the allegations. In early April 2007, the court denied the government’s motion for the case to remain under seal, and on April 23, 2007, the government filed a notice stating that it was not participating in the suit. In August 2007, the relator filed an amended complaint which added an additional contract to the allegations and added retaliation claims. We filed motions to dismiss and to compel arbitration which were granted on March 13, 2008 for all counts except as to the employment issues which were sent to arbitration. The relator filed an appeal and our position was upheld at the Appellate Court level as of January 6, 2010. As no further actions was taken by the relator with regard to the remaining employment issues sent to arbitration, we consider this matter to be concluded.

First Kuwaiti Trading Company arbitration. In April 2008, First Kuwaiti Trading Company, one of our LogCAP III subcontractors, filed for arbitration of a subcontract under which KBR had leased vehicles related to work performed on our LogCAP III contract. First Kuwaiti alleged that we did not return or pay rent for many of the vehicles and sought initial damages in the amount of $39 million. We filed a counterclaim to recover amounts which may ultimately be determined due to the Government for the $51 million in suspended costs as discussed in the preceding section of this footnote titled “Containers.” First Kuwaiti subsequently responded by adding additional subcontract claims, increasing its total claim to approximately $133 million as of June 30, 2010. The first of several arbitration hearings were held during the first quarter of 2010 involving unpaid rents and damages on vehicles and lost vehicles representing approximately $65 million of First Kuwaiti’s total claim. In the second quarter of 2010, the arbitration panel rejected the majority of First Kuwaiti’s claims which primarily related to unpaid rents beyond the expiration of the contractual lease term. The arbitration panel rendered a partial award to First Kuwaiti for damages of approximately $6 million plus an unquantified amount for repair costs on certain vehicles, damages suffered as a result of late vehicle returns, and interest thereon, to be determined at a later date. No payments are expected to occur until all claims are arbitrated and awards finalized. The remaining arbitration hearings are scheduled to occur throughout 2010 and we believe any damages ultimately awarded to First Kuwaiti will be billable under the LogCAP III contract. Accordingly, we have accrued amounts payable and a related unbilled receivable for the amounts awarded to First Kuwaiti pursuant to the terms of the contract.

Paul Morell, Inc. d/b/a The Event Source vs. KBR, Inc. TES is a former LogCAP III subcontractor who provided DFAC services at six sites in Iraq from mid-2003 to early 2004. TES sued KBR in Federal Court in Virginia for breach of contract and tortious interference with TES’s subcontractors by awarding subsequent DFAC contracts to the subcontractors. In addition, the Government withheld funds from KBR that KBR had submitted for reimbursement of TES invoices, and at that time, TES agreed that it was not entitled to payment until KBR was paid by the Government. Eventually KBR and the Government settled the dispute, and in turn KBR and TES agreed that TES would accept, as payment in full with a release of all other claims, the amount the Government paid to KBR for TES’s services. TES filed a suit to overturn that settlement and release, claiming that KBR misrepresented the facts. The trial was completed in June 2009 and in January 2010, the Federal Court issued an order against us in favor of TES in the amount of $15 million in actual damages and interest and $4 million in punitive damages relating to the settlement and release entered into by the parties in May 2005. We recorded un-reimbursable expenses of $19 million for the judgment received. As of December 31, 2009, the full amount of the damages and interest awarded to TES was accrued. In addition, we have filed a notice of appeal with the Court.

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Electrocution litigation. During 2008, a lawsuit was filed against KBR alleging that the Company was responsible for an electrical incident which resulted in the death of a soldier. This incident occurred at Al Taqaddum. It is alleged in the suit that the electrocution incident was caused by improper electrical maintenance or other electrical work. We intend to vigorously defend this matter. KBR denies that its conduct was the cause of the event and denies legal responsibility. The case was removed to Federal Court where motion to dismiss was filed. The court has issued a stay in the discovery of the case. The case is pending an appeal of certain pre-trial motions to dismiss that were previously denied. Hearings on the appeal were held in June 2010 and the court has taken the arguments under advisement. We are unable to determine the likely outcome nor can we estimate a range of potential loss, if any, related to this matter at this time. As of June 30, 2010, no amounts have been accrued.

Burn Pit litigation. KBR has been served with over 40 lawsuits in various states alleging exposure to toxic materials resulting from the operation of burn pits in Iraq or Afghanistan in connection with services provided by KBR under the LogCAP III contract. Each lawsuit has multiple named plaintiffs who purport to represent a large class of unnamed persons. The lawsuits primarily allege negligence, willful and wanton conduct, battery, intentional infliction of emotional harm, personal injury and failure to warn of dangerous and toxic exposures which has resulted in alleged illnesses for contractors and soldiers living and working in the bases where the pits are operated. All of the pending cases have been removed to Federal Court, the majority of which have been consolidated for multi-district litigation treatment. In the second quarter of 2010, we filed various motions including a motion to strike an amended consolidated petition filed by the plaintiffs and a motion to dismiss which the court has taken under advisement. We intend to vigorously defend these matters. Due to the inherent uncertainties of litigation and because the litigation is at a preliminary stage, we cannot at this time accurately predict the ultimate outcome nor can we estimate a range of potential loss, if any, related to this matter at this time. Accordingly, as of June 30, 2010, no amounts have been accrued.

Convoy Ambush litigation. In April 2004, a fuel convoy in route from Camp Anaconda to Baghdad International Airport for the U.S. Army under our LogCAP III contract was ambushed resulting in deaths and severe injuries to truck drivers hired by KBR. In 2005, survivors of the drivers killed and those that were injured in the convoy, filed suit in state court in Houston, Texas against KBR and several of its affiliates, claiming KBR deliberately intended that the drivers in the convoy would be attacked and wounded or killed. The suit also alleges KBR committed fraud in its hiring practices by failing to disclose the dangers associated with working in the Iraq combat zone. In September 2006, the case was dismissed based upon the court’s ruling that it lacked jurisdiction because the case presented a non-justiciable political question. Subsequently, three additional suits were filed, arising out of insurgent attacks on other convoys that occurred in 2004 and were likewise dismissed as non-justiciable under the Political Question Doctrine.

The plaintiffs in all cases appealed the dismissals to the Fifth Circuit Court of Appeals which reversed and remanded the remaining cases to trial court. In July 2008, the trial court directed substantive discovery to commence including the re-submittal of dispositive motions on various grounds including the Defense Base Act and Political Question Doctrine. In February 2010, the trial court ruled in favor of the plaintiffs, denying two of our motions to dismiss the case. In March 2010, the trial court granted in part and denied in part our third motion to dismiss the case. In March 2010, we filed appeals on all issues with the Fifth Circuit Court of Appeals and have moved to stay all proceedings in the trial court pending the resolution of these appeals. The cases have been removed from the trial docket and the Fifth Circuit Court of Appeals will now hear all previous motions filed by both parties. We are unable to determine the likely outcome of these cases at this time. As of June 30, 2010, no amounts have been accrued nor can we estimate the amount of potential loss, if any.

DOJ False Claims Act complaint. On April 1, 2010, the DOJ filed a complaint in the U.S. District Court in the District of Columbia alleging certain violations of the False Claims Act related to the use of private security firms. The complaint alleges, among other things, that we made false or fraudulent claims for payment under the LogCAP III contract because we allegedly knew that they contained costs of services for or that included improper use of private security. We believe these sums were properly billed under our contract with the Army and that the use of private security was not prohibited under LogCAP III. We have filed motions to dismiss the complaint which are currently pending. We have not adjusted our revenues or accrued any amounts related to this matter.

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Other Matters

Claims. Included in unbilled receivables in the accompanying balance sheets are unapproved claims for costs incurred under various government contracts totaling $101 million at June 30, 2010 and $113 million at December 31, 2009. Unapproved claims relate to contracts where our costs have exceeded the customer’s funded value of the task order. The unapproved claims at June 30, 2010 include approximately $59 million largely resulting from the de-obligation of 2004 funding on certain task orders that were also subject to Form 1 notices relating to certain DCAA audit issues discussed primarily under Dining Facilities above. The customer de-obligated funds which were nearing the 5-year expiration date of September 30, 2009. We believe such disputed costs will be resolved in our favor at which time the customer will be required to obligate funds from appropriations for the year in which resolution occurs. The unapproved claims outstanding at June 30, 2010 are considered to be probable of collection and have been recognized as revenue.

Note 7. Other Commitments and Contingencies

Foreign Corrupt Practices Act investigations

On February 11, 2009 KBR LLC, entered a guilty plea related to the Bonny Island investigation in the United States District Court, Southern District of Texas, Houston Division (the “Court”). KBR LLC pled guilty to one count of conspiring to violate the FCPA and four counts of violating the FCPA, all arising from the intent to bribe various Nigerian officials through commissions paid to agents working on behalf of TSKJ on the Bonny Island project. The plea agreement reached with the DOJ resolves all criminal charges in the DOJ’s investigation into the conduct of KBR LLC relating to the Bonny Island project, so long as the conduct was disclosed or known to DOJ before the settlement, including previously disclosed allegations of coordinated bidding. The plea agreement called for the payment of a criminal penalty of $402 million, of which Halliburton was obligated to pay $382 million under the terms of the indemnity in the master separation agreement, while we were obligated to pay $20 million. The criminal penalties are to be paid in quarterly payments over a two-year period ending October 2010. We also agreed to a period of organizational probation of three years, during which we retain a monitor who assesses our compliance with the plea agreement and evaluate our FCPA compliance program over the three year period, with periodic reports to the DOJ.

On the same date, the SEC filed a complaint and we consented to the filing of a final judgment against us in the Court. The complaint and the judgment were filed as part of a settled civil enforcement action by the SEC, to resolve the civil portion of the government’s investigation of the Bonny Island project. The complaint alleges civil violations of the FCPA’s antibribery and books-and-records provisions related to the Bonny Island project. The complaint enjoins us from violating the FCPA’s antibribery, books-and-records, and internal-controls provisions and requires Halliburton and KBR, jointly and severally, to make payments totaling $177 million, all of which has been paid by Halliburton pursuant to the indemnification under the master separation agreement. The judgment also requires us to retain an independent monitor on the same terms as the plea agreement with the DOJ.

Under both the plea agreement and judgment, we have agreed to cooperate with the SEC and DOJ in their investigations of other parties involved in TSKJ and the Bonny Island project.

As a result of the settlement, in the fourth quarter 2008 we recorded the $402 million obligation to the DOJ and, accordingly, recorded a receivable from Halliburton for the $382 million that Halliburton will pay to the DOJ on our behalf. The resulting charge of $20 million to KBR was recorded in cost of sales of our Hydrocarbons business unit in the fourth quarter of 2008. Likewise, we recorded an obligation to the SEC in the amount of $177 million and a receivable from Halliburton in the same amount. Halliburton paid seven installments totaling $335 million to the DOJ and $177 million to the SEC as of June 30, 2010, and such payments totaled $512 million. Of the payments mentioned above, Halliburton paid $95 million in the first six months of 2010 and $322 million in the first six months of 2009, which have been reflected in the accompanying statement of cash flows as noncash operating activities. We have paid a total of approximately $14 million related to our portion of the settlement agreement.

At June 30, 2010, the remaining obligation to the DOJ of $53 million has been classified on our condensed consolidated balance sheet in “Other current liabilities.” This classification is based on payment terms that provide for quarterly installments of $50 million each due on the first day of each subsequent quarter beginning on April 1, 2009 through October 1, 2010. Likewise, the remaining indemnification receivable from Halliburton for the DOJ obligation of $48 million has been classified on our condensed consolidated balance sheet in “Other current assets.”

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As part of the settlement of the FCPA matters, we have agreed to the appointment of a corporate monitor for a period of up to three years. We proposed the appointment of a corporate monitor and received approval from the DOJ in the third quarter of 2009. We are responsible for paying the fees and expenses related to the monitor’s review and oversight of our policies and activities relating to compliance with applicable anti-corruption laws and regulations.

Because of the guilty plea by KBR LLC, we are subject to possible suspension or debarment of our ability to contract with governmental agencies of the United States and of certain foreign countries. We received written confirmation from the U.S. Department of the Army stating that it does not intend to suspend or debar KBR from DoD contracting as a result of the guilty plea by KBR LLC. The U.K. Ministry of Defence (“MoD”) has indicated that it does not have any grounds to debar the KBR subsidiary with which it contracts under its public procurement regulations. Although there has been a threat to challenge the MOD’s decision not to debar KBR, no formal proceedings have been issued since the threat was made. Therefore, we believe the risk of being debarred from contracting with the MOD is considered low. Although we do not believe we will be suspended or debarred of our ability to contract with other governmental agencies of the United States or any other foreign countries, suspension or debarment from the government contracts business would have a material adverse effect on our business, results of operations, and cash flow.

Under the terms of the Master Separation Agreement, Halliburton has agreed to indemnify us, and any of our greater than 50%-owned subsidiaries, for our share of fines or other monetary penalties or direct monetary damages, including disgorgement, as a result of claims made or assessed by a governmental authority of the United States, the United Kingdom, France, Nigeria, Switzerland or Algeria or a settlement thereof relating to FCPA and related corruption allegations, which could involve Halliburton and us through The M. W. Kellogg Company, M. W. Kellogg Limited (“MWKL”), or their or our joint ventures in projects both in and outside of Nigeria, including the Bonny Island, Nigeria project. Halliburton’s indemnity will not apply to any other losses, claims, liabilities or damages assessed against us as a result of or relating to FCPA matters and related corruption allegations or to any fines or other monetary penalties or direct monetary damages, including disgorgement, assessed by governmental authorities in jurisdictions other than the United States, the United Kingdom, France, Nigeria, Switzerland or Algeria, or a settlement thereof, or assessed against entities such as TSKJ, in which we do not have an interest greater than 50%. As of June 30, 2010, we are not aware of any uncertainties related to the indemnity from Halliburton nor any material limitations on our ability to recover amounts due to us for matters covered by the indemnity from Halliburton.

We are aware that the U.K. Serious Fraud Office (“SFO”) is conducting an investigation of activities conducted by current or former employees of MWKL regarding the Bonny Island project. Violations of corruption laws in the U.K. could result in fines, restitution and confiscation of revenues, among other penalties. MWKL has self reported to the SFO its corporate liability for corruption-related offenses arising out of the Bonny Island project and expects to enter into a plea negotiation process under the “Attorney General’s Guidelines on Plea Discussions in Cases of Serious and Complex Fraud” issued by the Attorney General for England and Wales. MWKL is in the process of responding to inquiries and providing information as requested by the SFO. As a result of the unique factors associated with this matter and in light of MWKL’s cooperation, the SFO has confirmed it will treat MWKL as having made an early self report in accordance with the SFO’s guidelines. Whether the SFO pursues criminal prosecution or civil recovery, and the amount of any fines, restitution, confiscation of revenues or other penalties that could be assessed will depend on, among other factors, the SFO’s findings regarding the amount, timing, nature and scope of any improper payments or other activities, whether any such payments or other activities were authorized by or made with knowledge of MWKL, the amount of revenue involved, and the level of cooperation provided to the SFO during the investigations. Our indemnity from Halliburton under the master separation agreement with respect to MWKL is limited to our 55% beneficial ownership in MWKL. Due to the indemnity from Halliburton, we believe any outcome of this matter will not have a material adverse impact to our operating results or financial position. Investigations by other foreign governmental authorities are continuing. At this time, other than the claims being considered by the SFO discussed above, no claims by governmental authorities in foreign jurisdictions have been asserted.

Commercial Agent Fees

We have both before and after the separation from our former parent used commercial agents on some of our large-scale international projects to assist in understanding customer needs, local content requirements, vendor selection criteria and processes and in communicating information from us regarding our services and pricing. Prior to separation, it was identified by our former parent in performing its investigation of anti-corruption activities that certain of these agents may have engaged in activities that were in violation of anti-corruption laws at that time and the terms of their agent agreements with us. Accordingly, we have ceased the receipt of services from and payment of fees to these agents. Fees for these agents are included in the total estimated cost for these projects at their completion. In connection with actions taken by U.S. Government authorities, we have removed certain unpaid agent fees from the total estimated costs in the period that we obtained sufficient evidence to conclude such agents clearly violated the terms of their contracts with us. In the first and third quarters of 2009, we reduced project cost estimates by $16 million and $5 million, respectively, as a result of making such determinations. We have initiated a dialogue with some of the agents in question to explore the possibility of achieving resolution of these matters in accordance with our existing compliance procedures. As of June 30, 2010, agent fees of approximately $90 million are included in our estimated costs for various projects. We will make no payments to these agents until we are assured that any payment complies with all applicable laws.

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Barracuda-Caratinga Project Arbitration

In June 2000, we entered into a contract with Barracuda & Caratinga Leasing Company B.V., the project owner, to develop the Barracuda and Caratinga crude oilfields, which are located off the coast of Brazil. Petrobras is a contractual representative that controls the project owner. In November 2007, we executed a settlement agreement with the project owner to settle all outstanding project issues except for the bolts arbitration discussed below.

At Petrobras’ direction, we replaced certain bolts located on the subsea flowlines that failed through mid-November 2005, and we understand that additional bolts failed thereafter, which were replaced by Petrobras. These failed bolts were identified by Petrobras when it conducted inspections of the bolts. In March 2006, Petrobras notified us they submitted this matter to arbitration claiming $220 million plus interest for the cost of monitoring and replacing the defective stud bolts and, in addition, all of the costs and expenses of the arbitration including the cost of attorneys' fees. The arbitration is being conducted in New York under the guidelines of the United Nations Commission on International Trade Law (“UNCITRAL”). Petrobras contends that all of the bolts installed on the project are defective and must be replaced.

During the time that we addressed outstanding project issues and during the conduct of the arbitration, KBR believed the original design specification for the bolts was issued by Petrobras, and as such, the cost resulting from any replacement would not be our responsibility. A hearing on legal and factual issues relating to liability with the arbitration panel was held in April 2008. In June 2009, we received an unfavorable ruling from the arbitration panel on the legal and factual issues as the panel decided the original design specification for the bolts originated with KBR and its subcontractors. The ruling concluded that KBR’s express warranties in the contract regarding the fitness for use of the design specifications for the bolts took precedence over any implied warranties provided by the project owner. Our potential exposure would include the costs of the bolts replaced to date by Petrobras, any incremental monitoring costs incurred by Petrobras and damages for any other bolts that are subsequently found to be defective. We believe that it is probable that we have incurred some liability in connection with the replacement of bolts that have failed during the contract warranty period which expired June 30, 2006. In May 2010, the arbitration tribunal heard arguments from both parties regarding various damage scenarios and estimates of the amount of KBR’s overall liability in this matter. The final arbitration arguments will be made in August of 2010. Based on the damage estimates presented at this hearing, we estimate our minimum exposure, excluding interest, to be approximately $12 million representing our estimate for replacement of bolts that failed during the warranty period and were not replaced. During the second quarter of 2010, we recorded a liability of $12 million. Likewise, we recorded an indemnification receivable from Halliburton in the amount of $12 million. The amount of any remaining liability will be dependent upon the legal and factual issues to be determined by the arbitration tribunal in the final arbitration hearings. For the remaining bolts at dispute, we can not determine that we have liability nor determine the amount of any such liability and no additional amounts have been accrued.

Any liability incurred by us in connection with the replacement of bolts that have failed to date or related to the remaining bolts at dispute in the bolt arbitration is covered by an indemnity from our former parent Halliburton. Under the master separation agreement, Halliburton has agreed to indemnify us and any of our greater than 50%-owned subsidiaries as of November 2006, for all out-of-pocket cash costs and expenses (except for ongoing legal costs), or cash settlements or cash arbitration awards in lieu thereof, we 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. As of June 30, 2010, we are not aware of any uncertainties related to the indemnity from Halliburton nor any material limitations on our ability to recover amounts due to us for matters covered by the indemnity from Halliburton. We do not believe any outcome of this matter will have a material adverse impact to our operating results or financial position.

Index

Foreign tax laws

We conduct operations in many tax jurisdictions throughout the world. Tax laws in certain of these jurisdictions are not as mature as those found in highly developed economies. As a consequence, although we believe we are in compliance with such laws, interpretations of these laws could be challenged by the foreign tax authorities. In many of these jurisdictions, non-income based taxes such as property taxes, sales and use taxes, and value-added taxes are assessed on our operations in that particular location. While we strive to ensure compliance with these various non-income based tax filing requirements, there have been instances where potential non-compliance exposures have been identified. In accordance with accounting principles generally accepted in the United States of America, we make a provision for these exposures when it is both probable that a liability has been incurred and the amount of the exposure can be reasonably estimated. To date, such provisions have been immaterial, and we believe that, as of June 30, 2010, we adequately provided for such contingencies. However, it is possible that our results of operations, cash flows, and financial position could be adversely impacted if one or more non-compliance tax exposures are asserted by any of the jurisdictions where we conduct our operations.

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 Resources Conservation and Recovery Act; the Clean Air Act; the Federal Water Pollution Control Act; and the Toxic Substances Control Act.

In addition to federal and state laws and regulations, other countries where we do business often have numerous environmental regulatory requirements by which we must abide in the normal course of our operations. The portions of our business to which these requirements apply primarily relates to our Gas Monetization, Oil & Gas, Downstream and Services business units where we perform construction and industrial maintenance services or operate and maintain facilities. For certain locations, including our property at Clinton Drive, we have not completed our analysis of the site conditions and until further information is available, we are only able to estimate a possible range of remediation costs. These locations were primarily utilized for manufacturing or fabrication work and are no longer in operation. The use of these facilities created various environmental issues including deposits of metals, volatile and semi-volatile compounds, and hydrocarbons impacting surface and subsurface soils and groundwater. The range of remediation costs could change depending on our ongoing site analysis and the timing and techniques used to implement remediation activities. We do not expect costs related to environmental matters will have a material adverse effect on our condensed consolidated financial position or results of operations. Based on the information presently available to us, we have accrued approximately $7 million for the assessment and remediation costs associated with all environmental matters, which represents the low end of the range of possible costs that could be as much as $14 million.

Letters of credit

In connection with certain projects, we are required to provide letters of credit, surety bonds or other financial and performance guarantees to our customers. As of June 30, 2010, we had approximately $507 million in letters of credit and financial guarantees outstanding, of which $326 million were issued under our Revolving Credit Facility and $181 million issued under uncommitted bank lines. We have an additional $197 million of letters of credit that were issued under various other facilities and are irrevocably and unconditionally guaranteed by Halliburton.

Other

We had commitments to provide funds to our privately financed and other projects of $47 million as of June 30, 2010 and $52 million as of December 31, 2009. Commitments to fund these projects are supported by letters of credit as described above. At June 30, 2010, approximately $19 million of the $47 million in commitments will become due within one year.

Effective December 24, 2009, we entered into a collaboration agreement with BP p.l.c. to market and license certain technology. In conjunction with this arrangement, we acquired a license granting us the exclusive right to the technology. In January 2010, as partial consideration for the license, we paid an initial fee of $20 million, which will be amortized on a straight-line basis over the 25-year life of the arrangement.

Index

Liquidated damages

Many of our engineering and construction contracts have milestone due dates that must be met or we may be subject to penalties for liquidated damages if claims are asserted and we were responsible for the delays. These generally relate to specified activities that must be met within a project by a set contractual date or achievement of a specified level of output or throughput of a plant we construct. Each contract defines the conditions under which a customer may make a claim for liquidated damages. However, in some instances, liquidated damages are not asserted by the customer, but the potential to do so is used in negotiating claims and closing out the contract.

We have not accrued for liquidated damages related to several projects, including the exposure described in the above paragraph, totaling $19 million at June 30, 2010 and $18 million at December 31, 2009 (including amounts related to our share of unconsolidated subsidiaries), that we could incur based upon completing the projects as forecasted.

Leases

We are obligated under operating leases, principally for the use of land, offices, equipment, field facilities, and warehouses. We recognize minimum rental expenses over the term of the lease. When a lease contains a fixed escalation of the minimum rent or rent holidays, we recognize the related rent expense on a straight-line basis over the lease term and record the difference between the recognized rental expense and the amounts payable under the lease as deferred lease credits. We have certain leases for office space where we receive allowances for leasehold improvements. We capitalize these leasehold improvements as property, plant, and equipment and deferred lease credits. Leasehold improvements are amortized over the shorter of their economic useful lives or the lease term.

In February 2010, we executed two lease amendments for office space located in two separate high-rise office buildings in Houston, Texas for the purpose of significantly expanding our current leased office space and to extend the original term of the leases to June 30, 2030. These amendments did not change our historical accounting for these agreements as operating leases. The essential provisions of the lease amendments are as follows:

601 Jefferson Building Lease. The lease amendment extends the original term of the lease to June 30, 2030 and includes renewal options for three consecutive additional periods from 5 to 10 years each at prevailing market rates. Annual base rent for the leased office space escalates ratably over the lease term from $9 million to $14 million. The lease amendment includes a leasehold improvement allowance of $29 million primarily for the construction of leasehold improvements. The lease may be terminated under a one-time option in March 2022 for all, or a portion, of the leased premises subject to a termination fee. The 601 Jefferson building is owned by a joint venture in which KBR owns 50% interest with an unrelated party owning the remaining 50% interest. The joint venture is currently evaluating options to finance the leasehold improvement allowance including debt that is non-recourse to the joint venture partners or capital contributions from each partner on a pro-rata basis according to ownership interest. The nature of the funding for the leasehold improvement allowance has not yet been determined.

500 Jefferson Building Lease. The lease amendment extends the original term of the lease to June 30, 2030 and includes renewal options for three consecutive additional periods from 5 to 10 years each at prevailing market rates. The lease terms include a rent holiday for the first six months of the lease beginning July 1, 2010. Annual base rent for the leased office space escalates ratably over the lease term from $2 million to $3 million. The lease amendment includes a leasehold improvement allowance of $6 million primarily for the construction of leasehold improvements. The lease may be terminated under a one-time option in March 2022 for all, or a portion, of the leased premises subject to a termination fee.

Note 8. Income Taxes

Our effective tax rate was approximately 36% for the three and six months ended June 30, 2010. Our effective tax rate for the three and six months ended June 30, 2009 was approximately 37%. Our effective tax rate for the three and six months ended June 30, 2010 was higher than our statutory rate of 35% primarily due to discrete items charged to income tax expense related to increased tax accruals due to several items including Subpart F income and true-up of prior year foreign taxes. Our effective tax rate for the three and six months of 2009 was higher than our statutory rate of 35% primarily due to discrete items charged to income tax expense from the true-up of prior year foreign and domestic taxes.

Index

Note 9. Shareholders’ Equity

The following tables summarize our shareholders’ equity activities in the first six months of 2010:

				KBR Shareholders
Millions of dollars	Total				Paid-in Capital in Excess of par			Retained Earnings			Treasury Stock			Accumulated Other Comprehensive Loss			Noncontrolling Interests
Balance at December 31, 2009	$	2,296			$	2,103		$	854			(225	)	$	(444	)	$	8

Stock-based compensation		8				8			—			—			—			—
Common stock issued upon exercise of stock options		1				1			—			—			—			—
Tax benefit related to stock-based plans		—				—			—			—			—			—
Dividends declared to shareholders		(8	)			—			(8	)		—			—			—
Adjustments pursuant to tax sharing agreement with former parent		(8	)			(8	)		—			—			—			—
Repurchases of common stock		(58	)			—			—			(58	)		—			—
Issuance of ESPP shares		2				—			—			2			—			—
Dividends paid to noncontrolling interests		(30	)			—			—			—			—			(30	)
Consolidation of Fasttrax Limited		(4	)			—			—			—			—			(4	)
Comprehensive income:
Net income		181				—			152			—			—			29
Other comprehensive income, net of tax (provision):
Net cumulative translation adjustment		(6	)			—			—			—			(4	)		(2	)
Pension liability adjustment, net of tax		6				—			—			—			5			1
Net unrealized gains (losses) on derivatives		4				—			—			—			4			—
Total		185

Balance at June 30, 2010	$	2,384			$	2,104		$	998		$	(281	)	$	(439	)	$	2

The following tables summarize our shareholders’ equity activities for the first six months of 2009:

				KBR Shareholders
Millions of dollars	Total				Paid-in Capital in Excess of par		Retained Earnings			Treasury Stock			Accumulated Other Comprehensive Loss			Noncontrolling Interests
Balance at December 31, 2008	$	2,034			$	2,091	$	596			(196	)	$	(439	)	$	(18	)

Stock-based compensation		8				8		—			—			—			—
Dividends declared to shareholders		(8	)			—		(8	)		—			—			—
Repurchases of common stock		(21	)			—		—			(21	)		—			—
Dividends paid to noncontrolling interests		(21	)			—		—			—			—			(21	)
Investments by noncontrolling interests		12				—		—			—			—			12
Comprehensive income:
Net income		178				—		144			—			—			34
Other comprehensive income, net of tax (provision):
Net cumulative translation adjustment		10				—		—			—			6			4
Pension liability adjustment, net of tax		10				—		—			—			7			3
Net unrealized gains (losses) on derivatives		(2	)			—		—			—			(2	)		—
Total		196

Balance at June 30, 2009	$	2,200			$	2,099	$	732		$	(217	)	$	(428	)	$	14

Accumulated other comprehensive loss consisted of the following balances:

	June 30,			December 31,
Millions of dollars	2010			2009
Cumulative translation adjustments	$	(58	)	$	(54	)
Pension liability adjustments		(381	)		(386	)
Unrealized losses on derivatives		—			(4	)
Total accumulated other comprehensive loss	$	(439	)	$	(444	)

Index

Note 10. Fair Value Measurements

The financial assets and liabilities measured at fair value on a recurring basis are included below:

	Fair Value Measurements at Reporting Date Using
Millions of dollars	June 30, 2010		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)

Marketable securities	$	16	$	11	$	5	$	—

Derivative assets	$	18	$	—	$	18	$	—

Derivative liabilities	$	2	$	—	$	2	$	—

Derivative instruments. Currency derivative instruments are carried on the condensed consolidated balance sheet at fair value and are primarily based upon market observable inputs and significant other observable inputs. We manage our currency exposures through the use of foreign currency derivative instruments denominated in our major currencies, which are generally the currencies of the countries for which we do the majority of our international business. We utilize derivative instruments to manage the foreign currency exposures related to specific assets and liabilities that are denominated in foreign currencies, and to manage forecasted cash flows denominated in foreign currencies generally related to long-term engineering and construction projects. The purpose of our foreign currency risk management activities is to protect us from the risk that the eventual dollar cash flow resulting from the sale and purchase of products and services in foreign currencies will be adversely affected by changes in exchange rates.

Marketable securities. We use quoted market prices and other observable inputs to determine the fair value of our marketable securities. These financial instruments primarily consist of mutual funds, exchange-traded fixed income securities and money market accounts.

Note 11. Equity Method Investments and Variable Interest Entities

We conduct some of our operations through joint ventures which are in partnership, corporate, undivided interest and other business forms and are principally accounted for using the equity method of accounting. Additionally, the majority of our joint ventures are also variable interest entities which are further described under “Variable Interest Entities.”

Equity Method Investments

Brown & Root Condor Spa (“BRC”) BRC is a joint venture in which we owned 49% interest. During the third quarter of 2007, we sold our 49% interest and other rights in BRC to Sonatrach for approximately $24 million resulting in a pre-tax gain of approximately $18 million which is included in “Equity in earnings (losses) of unconsolidated affiliates”. As of June 30, 2010, we have not collected the remaining $18 million due from Sonatrach for the sale of our interest in BRC, which is included in “Accounts receivable.” In the fourth quarter of 2008, we filed for arbitration in an attempt to force collection.

Variable Interest Entities

We account for variable interest entities (“VIEs”) in accordance with FASB ASC 810. As a result of the adoption of ASU 2009-17, Consolidations (Topic 810) – Improvements to Financial Reporting by Enterprises Involved with Variable Interest Entities, effective January 1, 2010, FASB ASC 810 requires the consolidation of VIEs in which a company has both the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and the obligation to absorb losses or the right to receive the benefits from the VIE that could potentially be significant to the VIE. If a reporting enterprise meets these conditions then it has a controlling financial interest and is the primary beneficiary of the VIE. We have applied the requirements of FASB ASC 810 on a prospective basis from the date of adoption.

Index

We assess all newly created entities and those with which we become involved to determine whether such entities are VIEs and, if so, whether or not we are their primary beneficiary. Most of the entities we assess are incorporated or unincorporated joint ventures formed by us and our partner(s) for the purpose of executing a project or program for a customer, such as a governmental agency or a commercial enterprise, and are generally dissolved upon completion of the project or program. Many of our long-term energy-related construction projects in our Hydrocarbons business group are executed through such joint ventures. Typically, these joint ventures are funded by advances from the project owner, and accordingly, require little or no equity investment by the joint venture partners but may require subordinated financial support from the joint venture partners such as letters of credit, performance and financial guarantees or obligations to fund losses incurred by the joint venture. Other joint ventures, such as privately financed initiatives in our Ventures business unit, generally require the partners to invest equity and take an ownership position in an entity that manages and operates an asset post construction.

As required by ASC 810-10, we perform a qualitative assessment to determine whether we are the primary beneficiary once an entity is identified as a VIE. A qualitative assessment begins with an understanding of the nature of the risks in the entity as well as the nature of the entity’s activities including terms of the contracts entered into by the entity, ownership interests issued by the entity and how they were marketed, and the parties involved in the design of the entity. We then identify all of the variable interests held by parties involved with the VIE including, among other things, equity investments, subordinated debt financing, letters of credit, and financial and performance guarantees, and significant, contracted service providers. Once we identify the variable interests, we determine those activities which are most significant to the economic performance of the entity and which variable interest holder has the power to direct those activities. Though infrequent, some of our assessments reveal no primary beneficiary because the power to direct the most significant activities that impact the economic performance is held equally by two or more variable interest holders who are required to provide their consent prior to the execution of their decisions. Most of the VIEs with which we are involved have relatively few variable interests and are primarily related to our equity investment, significant service contracts, and other subordinated financial support.

Unconsolidated VIEs

The following is a summary of the significant variable interest entities in which we have a significant variable interest, but we are not the primary beneficiary:

U.K. Road Projects. We are involved in four privately financed projects, executed through joint ventures, to design, build, operate, and maintain roadways for certain government agencies in the United Kingdom. We have a 25% ownership interest in each of these joint ventures and account for them using the equity method of accounting. The joint ventures have obtained financing through third parties that is nonrecourse to the joint venture partners. These joint ventures are variable interest entities; however, we are not the primary beneficiary of these joint ventures. As of June 30, 2010, these joint ventures had total assets and liabilities of $1.5 billion each. As of December 31, 2009, these joint ventures had total assets of $1.7 billion and total liabilities of $1.6 billion. Our maximum exposure to loss was $31 million at June 30, 2010, which represents our investment in these ventures.

Fermoy Road Project. We participate in a privately financed project executed through certain joint ventures formed to design, build, operate, and maintain a toll road in southern Ireland. The joint ventures were funded through debt and were formed with minimal equity. These joint ventures are variable interest entities; however, we are not the primary beneficiary of the joint ventures. We have up to a 25% ownership interest in the project’s joint ventures, and we are accounting for these interests using the equity method of accounting. As of June 30, 2010 and December 31, 2009, the joint ventures had combined total assets of $226 million and $271 million, and total liabilities of $252 million and $295 million, respectively. Our maximum exposure to loss was $2 million at June 30, 2010.

Allenby & Connaught Project. In April 2006, Aspire Defence, a joint venture between us, Carillion Plc. and two financial investors, was awarded a privately financed project contract, the Allenby & Connaught project, by the MoD to upgrade and provide a range of services to the British Army’s garrisons at Aldershot and around Salisbury Plain in the United Kingdom. In addition to a package of ongoing services to be delivered over 35 years, the project includes a nine-year construction program to improve soldiers’ single living, technical and administrative accommodations, along with leisure and recreational facilities. Aspire Defence manages the existing properties and is responsible for design, refurbishment, construction and integration of new and modernized facilities. We indirectly own a 45% interest in Aspire Defence, the project company that is the holder of the 35-year concession contract. In addition, we own a 50% interest in each of two joint ventures that provide the construction and the related support services to Aspire Defence. Our performance through the construction phase is supported by $89 million in letters of credit and surety bonds totaling approximately $15 million as of June 30, 2010, both of which have been guaranteed by Halliburton. Furthermore, our financial and performance guarantees are joint and several, subject to certain limitations, with our joint venture partners. The project is funded through equity and subordinated debt provided by the project sponsors and the issuance of publicly held senior bonds which are nonrecourse to us. The entities we hold an interest in are variable interest entities; however, we are not the primary beneficiary of these entities. We account for our interests in each of the entities using the equity method of accounting. As of June 30, 2010, the aggregate total assets and total liabilities of the variable interest entities were both $2.9 billion. As of December 31, 2009, the aggregate total assets and total liabilities of the variable interest entities were both $3.0 billion. Our maximum exposure to project company losses as of June 30, 2010 was $68 million. Our maximum exposure to construction and operating joint venture losses is limited to the funding of any future losses incurred by those entities under their respective contracts with the project company. As of June 30, 2010, our assets and liabilities associated with our investment in this project, within our condensed consolidated balance sheet, were $50 million and $27 million, respectively. The $41 million difference between our recorded liabilities and aggregate maximum exposure to loss was primarily related to our $44 million remaining commitment to fund subordinated debt to the project in the future.

Index

EBIC Ammonia Project. We have an investment in a development corporation that has an indirect interest in the Egypt Basic Industries Corporation (“EBIC”) ammonia plant project located in Egypt. We are performing the engineering, procurement and construction (“EPC”) work for the project and operations and maintenance services for the facility. We own 65% of this development corporation and consolidate it for financial reporting purposes. The development corporation owns a 25% ownership interest in a company that consolidates the ammonia plant which is considered a variable interest entity. The development corporation accounts for its investment in the company using the equity method of accounting. The variable interest entity is funded through debt and equity. Indebtedness of EBIC under its debt agreement is non-recourse to us. We are not the primary beneficiary of the variable interest entity. As of June 30, 2010, the variable interest entity had total assets of $618 million and total liabilities of $467 million. As of December 31, 2009, the variable interest entity had total assets of $598 million and total liabilities of $489 million. Our maximum exposure to loss related to our involvement with this project at June 30, 2010 was $52 million. As of June 30, 2010, our assets and liabilities associated with our investment in this project, within our condensed consolidated balance sheet, were $50 million and $10 million, respectively. The $42 million difference between our recorded liabilities and aggregate maximum exposure to loss was related to our investment balance and other receivables in the project as of June 30, 2010.

Other Liquefied Natural Gas (“LNG”) Projects. We have equity ownership in two joint ventures to execute EPC projects. Our equity ownership ranges from 33% to 50%, and these joint ventures are variable interest entities. We are not the primary beneficiary and thus account for these joint ventures using the equity method of accounting. At June 30, 2010 and December 31, 2009, these joint ventures had aggregate assets of $306 million and $410 million and aggregate liabilities of $285 million and $467 million, respectively. As of June 30, 2010, total assets and liabilities recorded within our balance sheets were $30 million and $3 million, respectively. Our aggregate, maximum exposure to loss related to these entities was $31 million at June 30, 2010, and comprises primarily our equity investment and contract receivables with both joint ventures.

Consolidated VIEs

The following is a summary of the significant VIEs where we are the primary beneficiary:

Fasttrax Limited Project. In December 2001, the Fasttrax Joint Venture (the “JV”) was created to provide to the United Kingdom Ministry of Defense (“MOD”) a fleet of 92 new heavy equipment transporters (“HETs”) capable of carrying a 72-ton Challenger II tank. The JV owns, operates and maintains the HET fleet and provides heavy equipment transportation services to the British Army. The purchase of the assets was completed in 2004, and the operating and service contracts related to the assets extend through 2023. The JV’s entity structure includes a parent entity and its 100%-owned subsidiary, Fasttrax Ltd (the “SPV”). KBR and its partner own each 50% of the parent entity.

The JV’s purchase of the assets was funded through the issuance of several series guaranteed secured bonds totaling approximately £84.9 million issued by the SPV including £12.2 million which was replaced in 2005 when the shareholders funded combined equity and subordinated debt of approximately £12.2 million. The bonds are guaranteed by Ambac Assurance U.K. Ltd under a policy that guarantees the schedule of principle and interest payments to the bond trustee in the event of non-payment by Fasttrax. The total amount of debt consolidated at June 30, 2010, was approximately $101 million of which $8 million was classified as “Current non-recourse project-finance debt of a variable interest entity” and $93 million was classified as “Noncurrent non-recourse project-finance debt of a variable interest entity” on KBR’s condensed consolidated balance sheet.

Index

The guaranteed secured bonds were issued in two classes consisting of Class A 3.5% Index Linked Bonds in the amount of £56 million and Class B 5.9% Fixed Rate Bonds in the amount of £16.7 million. Principal payments on both classes of bonds commenced in March 2005 and are due in semi-annual installments over the term of the bonds which end in 2021. Subordinated notes payable to our 50% partner initially bear interest at 11.25% increasing to 16% over the term of the note through 2025. Payments on the subordinated debt commenced in March 2006 and are due in semi-annual installments over the term of the note.

The combined principal installments for both classes of bonds and subordinated notes, including inflation adjusted bond indexation, due for the years ended December 31, 2010, 2011 and 2012 and thereafter total approximately £3 million, £6 million, £6 million and £67 million, respectively.

Effective January 1, 2010, upon the adoption of the newly issued guidance in FASB ASC 810 – Consolidation, we determined that we are the primary beneficiary of this project entity because we control the activities that most significantly impact economic performance of the entity. This variable interest entity, in which we have a 50% ownership interest, was previously accounted for using the equity method of accounting because no party absorbed the majority of the expected losses which was the determining factor under the superceded standard. We have applied the requirements of FASB ASC 810 on a prospective basis from the date of adoption. Upon consolidation of this joint venture, consolidated current assets increased by $26 million primarily related to cash and equivalents, consolidated noncurrent assets increased by $89 million related to property, plant and equipment, consolidated current liabilities increased by $10 million primarily related to accounts payable, and noncurrent liabilities increased by $112 million related to the outstanding senior bonds and subordinated debt issued to finance the JV’s operations. No gain or loss was recognized by KBR upon consolidation of this VIE. As of June 30, 2010 and December 31, 2009, the joint venture had total assets of $100 million and $117 million, and total liabilities of $102 million and $124 million, respectively. Assets collateralizing the JV’s senior bonds include cash and equivalents of $20 million and property, plant, and equipment of approximately $80 million, net of accumulated depreciation of $35 million as of June 30, 2010. The bonds of the SPV, being non-recourse to KBR, are shown on the face of our condensed consolidated balance sheet as “Non-recourse project-finance debt.”

Escravos Gas-to-Liquids (“GTL”) Project. During 2005, we formed a joint venture to engineer and construct a gas monetization facility. We own 50% equity interest and determined that we are the primary beneficiary of the joint venture which is consolidated for financial reporting purposes. At June 30, 2010 and December 31, 2009, the joint venture had $331 million and $387 million in total assets and $428 million and $482 million in total liabilities, respectively. There are no consolidated assets that collateralize the joint venture’s obligations. However, at June 30, 2010 and December 31, 2009, the joint venture had approximately $95 million and $128 million of cash, respectively, which mainly relate to advanced billings in connection with the joint venture’s obligations under the EPC contract.

Pearl GTL Project. In July 2006, we were awarded, through a 50%-owned joint venture, a contract with Qatar Shell GTL Limited to provide project management and cost-reimbursable engineering, procurement and construction management services for the Pearl GTL project in Ras Laffan, Qatar. The project, which is expected to be completed by 2011, consists of gas production facilities and a GTL plant. The joint venture is considered a VIE. We consolidate the joint venture for financial reporting purposes because we are the primary beneficiary. As of June 30, 2010, the Pearl joint venture had total assets of $172 million and total liabilities of $158 million. As of December 31, 2009, the Pearl joint venture had total assets of $157 million and total liabilities of $138 million.

Gorgon LNG Project. We have a 30% ownership in an Australian joint venture which was awarded a contract by Chevron for cost-reimbursable FEED and EPCM services to construct a LNG plant. The joint venture is considered a VIE, and, as a result of our being the primary beneficiary, we consolidate this joint venture for financial reporting purposes. As of June 30, 2010, the joint venture had total assets of $173 million and total liabilities of $184 million. As of December 31, 2009, the joint venture had total assets and total liabilities of $109 million.

Index

Note 12. Retirement Plans

The components of net periodic benefit cost related to pension benefits for the three and six months ended June 30, 2010 and 2009 were as follows:

	Three Months Ended June 30,
	2010						2009
Millions of dollars	United States			International			United States			International

Components of net periodic benefit cost:
Service cost	$	—		$	1		$	—		$	—
Interest cost		1			22			1			19
Expected return on plan assets		(1	)		(23	)		(1	)		(19	)
Recognized actuarial loss		1			4			1			3
Curtailment		—			—			—			—
Net periodic benefit cost	$	1		$	4		$	1		$	3

	Six Months Ended June 30,
	2010						2009
Millions of dollars	United States			International			United States			International

Components of net periodic benefit cost:
Service cost	$	—		$	1		$	—		$	2
Interest cost		2			44			2			37
Expected return on plan assets		(2	)		(46	)		(2	)		(40	)
Recognized actuarial loss		1			9			1			6
Curtailment		—			—			—			(4	)
Net periodic benefit cost	$	1		$	8		$	1		$	1

For the six months ended June 30, 2010, we contributed approximately $6 million of the $15 million we currently expect to contribute in 2010 to our international plans, and $1 million of the $3 million we currently expect to contribute to our domestic plans in 2010. During the second quarter of 2010, we agreed with the trustees of one of our international plans to contribute £34 million over a 10-year period beginning in 2010 at an annual rate of approximately £5.5 million during the first three years and £2.5 million thereafter.

In March 2009, we amended the terms and conditions of one of our international pension plans and ceased future service and benefit accruals for all plan participants. This action meets the definition of a curtailment under FASB ASC 715 - Compensation - Retirement Benefits, and resulted in a curtailment gain of approximately $4 million during the first quarter of 2009.

The components of net periodic benefit cost related to other postretirement benefits were immaterial for the three and six months ended June 30, 2010 and 2009.

Note 13. Acquisitions

On April 5, 2010, we acquired 100% of the outstanding common stock of Houston-based Energo Engineering (“Energo”) for approximately $16 million in cash, subject to an escrowed holdback amount of $6 million to secure working capital adjustments, indemnification obligations of the sellers, and other contingent obligations related to the operation of the business. As a result of the acquisition, we recognized goodwill of $6 million and other intangible assets of $3 million. Energo provides Integrity Management (IM) and advanced structural engineering services to the offshore oil and gas industry. Energo will be integrated into our Hydrocarbons segment, which will enable that business to expand its capabilities worldwide as well as support FEED and detailed design projects.

Index

Note 14. Transactions with Former Parent and Other Related Party Transactions

Our balance payable to Halliburton of $49 million at June 30, 2010 and $53 million at December 31, 2009, was comprised of amounts owed to Halliburton primarily for estimated outstanding income taxes under the tax sharing agreement.

We perform many of our projects through incorporated and unincorporated joint ventures. In addition to participating as a joint venture partner, we often provide engineering, procurement, construction, operations or maintenance services to the joint venture as a subcontractor. Where we provide services to a joint venture that we control and therefore consolidate for financial reporting purposes, we eliminate intercompany revenues and expenses on such transactions. In situations where we account for our interest in the joint venture under the equity method of accounting, we do not eliminate any portion of our revenues or expenses. We recognize the profit on our services provided to joint ventures that we consolidate and joint ventures that we record under the equity method of accounting primarily using the percentage-of-completion method. Total revenues from services provided to our unconsolidated joint ventures recorded in our consolidated statements of income were $43 million and $27 million for the three months ended June 30, 2010 and 2009, respectively and revenues of $78 million and $80 million for the six months ended June 30, 2010 and 2009, respectively. Income or loss from services provided to our unconsolidated joint ventures was income of $1 million and loss of $2 million for the three months ended June 30, 2010 and 2009, respectively and income of $7 million and loss of $8 million for the six months ended June 30, 2010, and 2009, respectively.

Note 15. Recent Accounting Pronouncements

In October 2009, the FASB issued Accounting Standards Update (“ASU”) 2009-13, Revenue Recognition (Topic 605) - Multiple-Deliverable Revenue Arrangements. ASU 2009-13 addresses the accounting for multiple-deliverable arrangements to enable vendors to account for products or services (deliverables) separately rather than as a combined unit. Specifically, this guidance amends the criteria in Subtopic 605-25, Revenue Recognition-Multiple-Element Arrangements, for separating consideration in multiple-deliverable arrangements. This guidance establishes a selling price hierarchy for determining the selling price of a deliverable, which is based on: (a) vendor-specific objective evidence; (b) third-party evidence; or (c) estimates. This guidance also eliminates the residual method of allocation and requires that arrangement consideration be allocated at the inception of the arrangement to all deliverables using the relative selling price method. In addition, this guidance significantly expands required disclosures related to a vendor's multiple-deliverable revenue arrangements. ASU 2009-13 is effective prospectively for revenue arrangements entered into or materially modified in fiscal years beginning on or after June 15, 2010. We are evaluating the impact that the adoption of ASU 2009-13 will have on our financial position, results of operations, cash flows and disclosures.

In January 2010, the FASB issued ASU No. 2010-06, Fair Value Measurements and Disclosures (Topic 820) – Improving Disclosures about Fair Value Measurements. This ASU requires some new disclosures and clarifies some existing disclosure requirements about fair value measurement as set forth in Codification Subtopic 820-10. The FASB’s objective is to improve these disclosures and, thus, increase the transparency in financial reporting. Specifically, ASU 2010-06 amends Codification Subtopic 820-10 to now require:

A reporting entity should disclose separately the amounts of significant transfers in and out of Level 1 and Level 2 fair value measurements and describe the reasons for the transfers; and

In the reconciliation for fair value measurements using significant unobservable inputs, a reporting entity should present separately information about purchases, sales, issuances, and settlements.

In addition, ASU 2010-06 clarifies the requirements of the following existing disclosures:

For purposes of reporting fair value measurement for each class of assets and liabilities, a reporting entity needs to use judgment in determining the appropriate classes of assets and liabilities; and

A reporting entity should provide disclosures about the valuation techniques and inputs used to measure fair value for both recurring and nonrecurring fair value measurements.

The ASU is effective for interim and annual reporting periods beginning after December 15, 2009, except for the disclosures about purchases, sales, issuances, and settlements in the roll forward of activity in Level 3 fair value measurements. Those disclosures are effective for fiscal years beginning after December 15, 2010, and for interim periods within those fiscal years. Early application is permitted. The adoption of this accounting standard update did not have a material impact on our financial position, results of operations, cash flows and disclosures.

Index

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

The purpose of management’s discussion and analysis (“MD&A”) is to increase the understanding of the reasons for material changes in our financial condition since the most recent fiscal year-end and results of operations during the current fiscal period as compared to the corresponding period of the preceding fiscal year. The MD&A should be read in conjunction with the condensed consolidated financial statements and accompanying notes and our 2009 Annual Report on Form 10-K.

Business Environment and Results of Operations

Business Reorganization

During the first quarter of 2010, we reorganized our business into discrete engineering and construction business units, each focused on a specific segment of the market with identifiable customers, business strategies, and sales and marketing capabilities. The reorganization includes the realignment of certain underlying projects among our existing business units as well as the transfer of certain projects to several newly formed business units. Certain realigned business units are reported under the newly formed Infrastructure, Government & Power (“IGP”) and Hydrocarbons business groups. Each business group is led by a business group president who reports directly to our chief operating decision maker. Our Services and Ventures business units will continue to operate as stand-alone business units reporting directly to our chief operating decision maker.

Business Environment

Hydrocarbon Markets

We provide a full range of engineering, procurement and construction services for large and complex upstream and downstream projects, including LNG and GTL facilities, onshore and offshore oil and gas production facilities, industrial, power generation and other projects. We serve customers in the gas monetization, oil and gas, petrochemical, refining, power and chemical markets throughout the world. Our projects are generally long term in nature and are impacted by factors including market conditions, financing arrangements, governmental approvals and environmental matters. Demand for our services depends primarily on our customers’ capital expenditures in our construction services.

We have benefited in recent years from increased capital expenditures from our petroleum and petrochemical customers driven by historically high crude oil and natural gas prices and general global economic expansion that occurred prior to mid-2008. We have indications that the hydrocarbons market in most geographical regions outside of North America has partially recovered from the worldwide economic recession and financial market condition. Specifically relating to construction and maintenance in the United States we continue to see projects proceeding predominately with smaller projects, focused on environmental, reliability and efficiency improvements. The Canadian oil sands market, which fell sharply in 2009, is rebounding and we are expecting increased activity throughout 2010 and into 2011. Our outlook for maintenance spending in North America is being influenced by the need of our customers to complete projects, previously deferred, that are now expected to proceed.

Infrastructure, Government and Power Markets

A significant portion of our IGP business group’s current activities support the United States’ and the United Kingdoms’ operations in Iraq, Afghanistan and in other parts of the Middle East region. These operations have resulted in one of the largest military deployments since World War II, which has caused a parallel increase in government spending. The logistics support services that KBR provides the U.S. military are delivered under our LogCAP III and LogCAP IV contracts, which are competitively bid contracts. KBR is the only company providing services under the LogCAP III contract. Currently, the U.S. government is transitioning work from LogCAP III to LogCAP IV, which is a multiple award contract with three contractors, including KBR, who can each bid and potentially win specific task orders. As troop deployments shift within the Middle East region, and as additional work is awarded under LogCAP IV, we have seen a decline in work under LogCAP III and we expect this decline will continue. We expect the U.K. military will remain engaged in the region, although their presence has shifted from Iraq to Afghanistan.

In the civil infrastructure sector, we operate in diverse sectors, including transportation, waste and water treatment and facilities maintenance. In addition to U.S. state, local and federal agencies, we provide these services to governments around the world including the U.K., Australia and the Middle East. In Australia, we also provide related services to the global mining industry. There has been a general trend of historic under-investment in infrastructure, particularly related to the quality of water, wastewater, roads and transit, airports, and educational facilities which has historically declined while demand for expanded and improved infrastructure has historically outpaced funding. We have seen increased activity related to these types of projects, however, the global economic recession has caused a slow down in some projects. Stimulus spending and a general economic recovery should result in increased opportunities in the future across all sectors.

Index

In the industrial sector, we operate in a number of markets, including forest products, minerals and metals and consumer products, with a heavy domestic focus, but with our international opportunities increasing. Forest products and consumer products are seeing some market improvements with minerals and metals markets sensitive to potential stimulus spending. In the power sector, we serve both utility and independent power producers, also with a heavy domestic focus. This market continues to be driven by air quality related projects and new generation projects, including renewables. Future Federal regulations and stimulus programs could have a significant impact on both components of the market, but the timing and magnitude is not readily predictable at this time.

We provide a wide range of construction and maintenance services to a variety of industries in the U.S. and Canada, including forest products, power, commercial buildings, general industrial and manufacturing. Similar to the Hydrocarbons’s markets, we see projects moving forward that are focused on meeting statutory requirements and efficiency improvements rather than capacity expansion. Despite the volatility in economic conditions throughout 2009, we continued to see an increase in prequalification requests from our clients and expect a number of our markets to strengthen in 2010 and 2011.

For a more detailed discussion of the results of operations for each of our business groups and business units, corporate general and administrative expense, income taxes and other items, see “Results of Operations” below.

Results of Operations

We analyze the financial results for each of our business groups and business units. The business groups presented are consistent with our reportable operating segments discussed in Note 4 (Business Segment Information) to our condensed consolidated financial statements. While certain of the business groups and business units presented below do not meet the criteria for reportable segments in accordance with FASB ASC 280 – Segment Reporting, we believe this supplemental information is relevant and meaningful to our investors for various reasons including monitoring our progress and growth in certain markets and product lines.

Index

For purposes of reviewing the results of operations, “business unit income” is calculated as revenue less cost of services managed and reported by the business unit and are directly attributable to the business unit. Business unit income excludes corporate general and administrative expenses and other non-operating income and expense items.

Revenue by Business Unit

	Three Months Ended June 30,
Millions of dollars	2010		2009		Increase (Decrease)			Percentage Change

Revenue: (1)
Hydrocarbons:
Gas Monetization	$	708	$	679	$	29			4	%
Oil & Gas		104		107		(3	)		(3	)%
Downstream		157		124		33			27	%
Technology		35		23		12			52	%
Total Hydrocarbons business group revenue		1,004		933		71			8	%

Infrastructure, Government and Power (“IGP”):
North America Government and Defense		926		1,394		(468	)		(34	)%
International Government and Defense		103		67		36			54	%
Infrastructure and Minerals		64		86		(22	)		(26	)%
Power and Industrial		104		111		(7	)		(6	)%
Total IGP business group revenue		1,197		1,658		(461	)		(28	)%

Services		452		498		(46	)		(9	)%
Ventures		13		3		10			333	%
Other		5		9		(4	)		(44	)%
Total revenue	$	2,671	$	3,101	$	(430	)		(14	)%

________________________

(1)

Our revenue includes both equity in the earnings of unconsolidated affiliates as well as revenue from the sales of services into the joint ventures. We often participate on larger projects as a joint venture partner and also provide services to the venture as a subcontractor. The amount included in our revenue represents our share of total project revenue, including equity in the earnings (loss) from joint ventures and revenue from services provided to joint ventures.

Index

Income (loss) by Business Unit

	Three Months Ended June 30,
Millions of dollars	2010			2009			Increase (Decrease)			Percentage Change

Business Unit Income (loss):
Hydrocarbons:
Gas Monetization	$	83		$	50		$	33			66	%
Oil & Gas		13			26			(13	)		(50	)%
Downstream		28			20			8			40	%
Technology		17			11			6			55	%
Total job income		141			107			34			32	%
Gain on disposition of assets		1			—			1			—
Divisional overhead		(26	)		(24	)		(2	)		(8	)%
Total Hydrocarbons business group income		116			83			33			40	%
Infrastructure, Government and Power (“IGP”):
North America Government and Defense		92			69			23			33	%
International Government and Defense		22			21			1			5	%
Infrastructure and Minerals		15			20			(5	)		(25	)%
Power and Industrial		15			11			4			36	%
Total job income		144			121			23			19	%
Divisional overhead		(39	)		(35	)		(4	)		(11	)%
Total IGP business group income		105			86			19			22	%
Services:
Job income		43			41			2			5	%
Loss on disposition of assets		(1	)		—			(1	)		—
Divisional overhead		(17	)		(17	)		—			—
Total Services business unit income		25			24			1			4	%
Ventures:
Job income (loss)		8			2			6			300	%
Divisional overhead		(1	)		(1	)		—			—
Total Ventures business unit income		7			1			6			600	%
Other:
Job income		2			2			—			—
Divisional overhead		(3	)		(2	)		(1	)		(50	)%
Total Other business unit income		(1	)		—			(1	)		—

Total business unit income	$	252		$	194		$	58			30	%
Unallocated amounts:
Loss on disposition of assets - corporate		(2	)		—			(2	)		—
Labor costs absorption (1)		4			(3	)		7			233	%
Corporate general and administrative		(55	)		(54	)		(1	)		(2	)%
Total operating income	$	199		$	137		$	62			45	%

________________________

(1)	Labor cost absorption represents costs incurred by our central labor and resource groups (above)/under the amounts charged to the operating business units.

Index

Three months ended June 30, 2010 compared to three months ended June 30, 2009

Hydrocarbons Business Group

Gas Monetization. Revenues in the second quarter of 2010 in our Gas Monetization Operations increased by $29 million primarily due to increased activity from the Gorgon LNG and several other projects. Revenue from these projects increased $115 million in the aggregate in the second quarter of 2010 primarily as a result of the transition from the FEED to the EPCM portion of the Gorgon project as well as change orders on another LNG project that is nearing completion. Partially offsetting these increases in revenues was a decline in revenues of approximately $85 million due to lower activity on the Escravos GTL and Skikda LNG projects.

Gas Monetization job income increased approximately $33 million in the second quarter of 2010 compared to the same period of the prior year. Job income increased as a result of change orders on an LNG project executed through a joint venture that is now completed. The change orders executed on this LNG project primarily provided for relief of liquidated damages to the joint venture but were partially offset by increased subcontractor claims resulting in $36 million to job income during the second quarter of 2010.

Oil & Gas. Revenues from our Oil & Gas Operations decreased by approximately $3 million in the second quarter of 2010 as compared to the second quarter of 2009. The decrease in revenue is primarily due to the completion of several technical service projects as well as the EOS North Rankin project in Australia which is nearing completion. Partially offsetting these decreases in revenues were increases related to higher progress on new project awards including the COP Define, Jack St. Malo and other projects.

Job income in our Oil & Gas Operations in the second quarter of 2010 decreased by $13 million over the same quarter of the prior year. The decrease in Oil & Gas Operations job income is primarily due to various projects that were either completed in 2009 or nearing completion in the end of the second quarter of 2010.

Downstream. Downstream revenue in the second quarter of 2010 increased by $33 million primarily due to several petrochemical projects in the Middle East including the Ras Tanura, Shaybah and Sonangol projects which increased approximately $51 million in the aggregate as a result of increased activity over the prior year. These increases in revenues were partially offset by lower revenues on several chemical projects in North America as they were either completed or nearing completion.

Downstream job income in the second quarter of 2010 increased by approximately $8 million as compared to the same period of the prior year. The increase was primarily driven by increased activity on the Sonangol and Ras Tanura projects which contributed $14 million to job income in the aggregate. Additionally, Downstream job income in the second quarter of 2009 included $7 million in charges on our EBIC ammonia project due to additional costs related to the commissioning and start up of the plant which further contributed to the improvement in job income during the second quarter of 2010. Partially offsetting these increases in job income was a charge of approximately $9 million related to an accounts receivable reserve adjustment recorded in the second quarter of 2010.

Technology. Technology revenues and job income in the second quarter of 2010 increased $12 million and $6 million, respectively, primarily due to the progress achieved on a number of new projects including a grassroots ammonia and urea project in Turkmenistan, two ammonia projects in India and a petrochemical plant in China.

Infrastructure, Government and Power (“IGP”) Business Group

North America Government and Defense (“NAGD”). Revenue from our NAGD Operations decreased approximately $468 million in the second quarter of 2010 over the same period in the prior year. The decrease in NAGD revenue includes a $463 million decline resulting from an overall reduction in volume for U.S. military support activities primarily in Iraq under our LogCAP III contract. The lower volume is primarily due to the continued reductions in staff and personnel on the project as combat troop levels declined. We expect to continue providing services on certain task orders through 2011. Although the decreases in revenue on the LogCAP III project have been partially offset by a task order on the LogCAP IV contract, we expect our overall volume of work to continue to decrease in Iraq throughout the remainder of 2010. Also contributing to the decrease in NAGD revenue is $33 million less revenue as a result of lower volumes of work under the CENTCOM project.

Index

Job income from our NAGD Operations increased by approximately $23 million primarily as a result of award fees received on the LogCAP III contract which was partially offset by the overall reduction in volume of U.S. military support activities primarily in Iraq. Award fees on the LogCAP III project in the second quarter of 2010 were approximately $42 million higher as compared to the same period of the prior year. Prior to the fourth quarter of 2009, we accrued award fees based on the estimated amounts to be awarded. However, as a result of the U.S. Army’s Iraq Award Fee Evaluation Board decision in February 2010 to award zero award fees for certain prior periods of performance, we concluded that we could no longer estimate the amount of fees to be awarded. Therefore, we ceased accruing any further award fees until we can reliably estimate fees to be awarded in the future or when such fees are actually awarded. Subsequently, in May 2010, we received an award fee of approximately $60 million which was recorded as an increase to revenue and job income. The increase in job income on the LogCAP III project was partially offset primarily by lower volumes of activity.

International Government and Defense (“IGD”). Revenue from our IGD Operations increased approximately $36 million and job income was relatively flat for the second quarter of 2010 compared the same period in the prior year. The increase in revenue was primarily related to the increasing presence of troops in Afghanistan where we provide contingency logistics, operations and maintenance and other services to the U.K. MoD under the TDA, CONLOG and NAMSA projects. Job income in the second quarter of 2010 increased due to higher construction margins on the Allenby & Connaught project as well as higher volume of services for the CONLOG and other U.K. MoD projects. The increases were offset primarily due to decreases in job income on the Tier 3 Basra project which was completed in 2009.

Infrastructure and Minerals (“I&M”). Revenue from our I&M Operations decreased approximately $22 million in the second quarter of 2010 over the same period in the prior year due to lower overall activity on several projects including Southern Regional Water Pipeline and Hope Downs South Minerals projects in Australia, the Scottish Water project in the U.K. and the Yas Island Development project in Abu Dhabi. These projects have either been completed prior to the first quarter of 2010 or scaled down as a result of the global economic conditions. Additionally, new project awards have been either delayed or canceled further contributing to the decrease. Job income from our I&M Operations decreased in the second quarter of 2010 by approximately $5 million primarily as a result of the overall decrease in project activity and new project awards.

Power and Industrial (“P&I”). Revenue from our P&I Operations decreased approximately $7 million in the second quarter of 2010 over the same period in the prior year largely as a result of the completion of fieldwork on the Georgia Power plant project in April 2010 and lower profits on the Red River project in Louisiana. These decreases were partially offset by increased volume on a new waste-to-energy project in Florida and other projects. Job income from our P&I Operations increased by $4 million in the second quarter of 2010 primarily due to our waste-to-energy project and change orders on the completed Georgia Power plant project, offset partially by lower profits on the Red River project.

Services

Services revenues in the second quarter of 2010 decreased by $46 million as compared to the second quarter of 2009. Approximately $60 million of the decrease occurred in our Building Group due to lower volume. The building group was awarded several new projects including the Boeing 787 Assembly Facility and Alabama Children’s Hospital, although these projects did not significantly contribute to revenues in the second quarter of 2010 as they are executed through joint ventures that we do not control and are thus accounted for under the equity method of accounting. Additionally, revenues in our U.S. Construction Group declined $15 million primarily due to the completion of the Conoco Phillips Borger and ExxonMobil Flare Gas projects in 2009. Partially offsetting these decreases in revenues were increases of approximately $30 million in our Canadian and Industrial Services operations including higher progress on the Shell AOSP project in Canada and increased construction maintenance and services under a new contract for DuPont throughout the Eastern and Gulf Coast regions of the U.S.

Job income increased by approximately $2 million in the second quarter of 2010 over the second quarter of 2009. Job income resulting from the increased activity on the Shell AOSP, Hunt Refining and other projects were largely offset as a result of work that was substantially completed in 2009 including the Conoco Phillips Borger and ExxonMobil Flare Gas projects as well as the lower volume of new project awards in our Building Group and U.S. construction product lines.

Index

Ventures

Ventures revenue was $13 million and job income was $8 million in the second quarter of 2010 as compared to revenue of $3 million and job income of $2 million in the second quarter of 2009. The increase in revenue is primarily attributable to the consolidation of Fasttrax Limited, which is the primary contracting entity with the MoD in a project that owns and operates heavy equipment transport vehicles for the U.K. military. This variable interest entity, in which we have a 50% ownership interest, was previously accounted for using the equity method of accounting. Effective January 1, 2010, we determined we were the primary beneficiary pursuant to the adoption of in FASB ASC 810 – Consolidation in the first quarter of 2010. Ventures job income increased during the second quarter of 2010 primarily due to the consolidation of Fasttrax Ltd. as well as improved performance of the EBIC ammonia plant project which became operational in 2009. The EBIC ammonia plant performance benefitted from increased sales volume and higher ammonia prices than in the same quarter of the prior year.

Labor cost absorption. Labor cost absorption income was $4 million in the second quarter of 2010 and labor cost absorption expense was $3 million in the second quarter of 2009. Labor cost absorption represents costs incurred by our central labor and resource groups (above) or under the amounts charged to the operating business units. Labor cost absorption income increased in the second quarter of 2010 primarily due to higher chargeability and utilization in several of our engineering offices as well as higher incentive compensation which was partially offset by lower headcount. Partially offsetting these increases were lower costs due to closure of one of our offices in Lagos as well as lower costs under our 2009 incentive compensation plan.

Allocation of Services Business Unit to IGP and Hydrocarbons

The Services business segment provides construction and maintenance services to clients in a number of markets. Customer focus, attention to highly productive delivery, and a diverse market presence we believe are keys to our success in delivering construction and maintenance services. Accordingly, the Services business segment focuses on these key success factors. The analysis shown below is supplementally provided to present the revenues of our reportable business segments by market. The revenues managed by the Services business segment have been allocated based on the markets served by the Services business segment. The perspective highlights the markets served by our Services segment.

	Three Months Ended June 30, 2010
	Business Unit Revenue		Allocation of Services			Total Allocated Revenue
Hydrocarbons business group:
Gas Monetization	$	708	$	—		$	708
Oil & Gas		104		90			194
Downstream		157		144			301
Technology		35		—			35
Total Hydrocarbons business group revenue		1,004		234			1,238

Infrastructure, Government and Power (“IGP”):
North America Government and Defense		926		23			949
International Government and Defense		103		—			103
Infrastructure and Minerals		64		—			64
Power and Industrial		104		195			299
Total IGP business group revenue		1,197		218			1,415

Services		452		(452	)		—
Other		18		—			18
Total KBR Revenue	$	2,671	$	—		$	2,671

Index

	Three Months Ended June 30, 2009
	Business Unit Revenue		Allocation of Services			Total Allocated Revenue
Hydrocarbons business group:
Gas Monetization	$	679	$	—		$	679
Oil & Gas		107		77			184
Downstream		124		147			271
Technology		23		—			23
Total Hydrocarbons business group revenue		933		224			1,157

Infrastructure, Government and Power (“IGP”):
North America Government and Defense		1,394		18			1,412
International Government and Defense		67		—			67
Infrastructure and Minerals		86		—			86
Power and Industrial		111		256			367
Total IGP business group revenue		1,658		274			1,932

Services		498		(498	)		—
Other		12		—			12
Total KBR Revenue	$	3,101	$	—		$	3,101

Non-operating items

Net interest expense was $5 million in the second quarter of 2010 and zero in the second quarter of 2009. Interest expense increased in the second quarter primarily as a result of increased commitment fees paid under the terms of our new credit facility, increased rates associated with outstanding performance-related and financial-related issued letters of credit, and fees paid to Halliburton for guarantees provided to us for various financial commitments. Additionally, interest expense recognized in the second quarter of 2010 on non-recourse project-finance debt was $2 million higher due to the consolidation of Fasttrax Limited effective January 1, 2010. Interest income earned on our invested cash remained relatively flat for the second quarter of 2010 compared to the second quarter of 2009 as a result of the current economic conditions.

We had foreign currency losses of $3 million in the second quarter of 2010 and $4 million in the second quarter of 2009. Foreign currency losses in the second quarter of 2010 primarily resulted from the weakening Euro and from currencies with no hedge market such as the Algerian Dinar. The foreign currency loss of $4 million in the second quarter of 2009 primarily resulted from the remeasurement of monetary assets and liabilities in foreign jurisdictions as a result of the weakening of the U.S. dollar against certain foreign currencies, which include the British pound, Euro and Algerian dinar. Some of these positions were not fully hedged.

Provision for income taxes was $69 million in the second quarter of 2010 and $49 million in the second quarter of 2009. Our effective tax rate was approximately 36% for the three months ended March 31, 2010 and 37% for the three months ended March 31, 2009. Our effective tax rate for the second quarter of 2010 was higher than our statutory rate of 35% primarily due to discrete items charged to income tax expense related to increased tax accruals due to several items including Subpart F income and true-up of prior year foreign taxes. Our effective tax rate for the second quarter of 2009 was higher than our statutory rate of 35% primarily due to discrete items charged to income tax expense from the true-up of prior year foreign and domestic taxes.

Index

Revenue by Business Unit


	Six Months Ended June 30,
Millions of dollars	2010		2009		Increase (Decrease)			Percentage Change

Revenue: (1)
Hydrocarbons:
Gas Monetization	$	1,383	$	1,335	$	48			4	%
Oil & Gas		188		202		(14	)		(7	)%
Downstream		290		237		53			22	%
Technology		65		43		22			51	%
Total Hydrocarbons business group revenue		1,926		1,817		109			6	%

Infrastructure, Government and Power (“IGP”):
North America Government and Defense		1,936		2,957		(1,021	)		(35	)%
International Government and Defense		197		137		60			44	%
Infrastructure and Minerals		137		172		(35	)		(20	)%
Power and Industrial		201		215		(14	)		(7	)%
Total IGP business group revenue		2,471		3,481		(1,010	)		(29	)%

Services		867		973		(106	)		(11	)%
Ventures		28		11		17			155	%
Other		10		19		(9	)		(47	)%
Total revenue	$	5,302	$	6,301	$	(999	)		(16	)%

________________________

(1)

Index

Income (loss) by Business Unit

	Six Months Ended June 30,
Millions of dollars	2010			2009			Increase (Decrease)			Percentage Change

Business Unit Income (loss):
Hydrocarbons:
Gas Monetization	$	136		$	115		$	21			18	%
Oil & Gas		29			44			(15	)		(34	)%
Downstream		50			26			24			92	%
Technology		29			20			9			45	%
Total job income		244			205			39			19	%
Gain on disposition of assets		1			—			1			—
Divisional overhead		(53	)		(45	)		(8	)		(18	)%
Total Hydrocarbons business group income		192			160			32			20	%
Infrastructure, Government and Power (“IGP”):
North America Government and Defense		128			143			(15	)		(10	) %
International Government and Defense		40			35			5			14	%
Infrastructure and Minerals		33			44			(11	)		(25	)%
Power and Industrial		29			20			9			45	%
Total job income		230			242			(12	)		(5	)%
Divisional overhead		(79	)		(71	)		(8	)		(11	)%
Total IGP business group income		151			171			(20	)		(12	)%
Services:
Job income		80			77			3			4	%
Loss on disposition of assets		(1	)		—			(1	)		—
Divisional overhead		(33	)		(34	)		1			3	%
Total Services business unit income		46			43			3			7	%
Ventures:
Job income (loss)		17			10			7			70	%
Gain on disposition of assets		—			2			(2	)		(100	)%
Divisional overhead		(2	)		(1	)		(1	)		(100	)%
Total Ventures business unit income		15			11			4			36	%
Other:
Job income		4			5			(1	)		(20	)%
Divisional overhead		(4	)		(4	)		—			—
Total Other business unit income		—			1			(1	)		(100	)%

Total business unit income	$	404		$	386		$	18			5	%
Unallocated amounts:
Loss on disposition of assets - corporate		(2	)		—			(2	)		—
Labor costs absorption (1)		—			(2	)		2			100	%
Corporate general and administrative		(104	)		(103	)		(1	)		(1	)%
Total operating income	$	298		$	281		$	17			6	%

________________________

(1)	Labor cost absorption represents costs incurred by our central labor and resource groups (above)/under the amounts charged to the operating business units.

Index

Six months ended June 30, 2010 compared to six months ended June 30, 2009

Hydrocarbons Business Group

Gas Monetization. Revenues in the first six months of 2010 in our Gas Monetization Operations increased by $48 million primarily due to increased activity from the Gorgon LNG and several other projects. Revenue from these projects increased approximately $195 million in the first six months of 2010 primarily as a result of the transition from the FEED to the EPCM portion of the Gorgon project as well as change orders on another LNG project that is nearing completion. Partially offsetting the 2010 increases in Gas Monetization revenues are declines in revenues of approximately $147 million in the aggregate due to lower activity on other projects including the Pearl GTL, Escravos GTL and Skikda LNG projects.

Gas Monetization job income increased approximately $21 million in the first six months of 2010 compared to the same period of the prior year. Job income increased $61 million in the aggregate as a result of change orders on an LNG project executed through a joint venture that is now completed and increased activity on another LNG project. The change orders executed on the completed LNG project primarily provided for relief of liquidated damages to the joint venture but were partially offset by increased subcontractor claims resulting in a net increase of $36 million to job income during the second quarter of 2010. Partially offsetting these first quarter 2010 increases in Gas Monetization Operations job income were decreases in job income of approximately $35 million on other projects including the Pearl GTL, Escravos GTL and Skikda LNG projects due to lower activity. Additionally, job income in the first six months of 2009 included $10 million as a result of the reversal of certain commercial agent fees in the first six months of 2009.

Oil & Gas. Revenues from our Oil & Gas Operations decreased by approximately $14 million in the first six months of 2010 as compared to the first six months of 2009. The decrease in Oil & Gas Operations revenue is primarily due to the completion of a number of technical service projects as well as the EOS North Rankin and Pazflor which were nearing completion at the end of the second quarter of 2010. Revenue related to these projects decreased approximately $72 million in the aggregate in the first six months of 2010. Partially offsetting these decreases in revenue were increases of approximately $45 million in the aggregate related to new project awards including the COP Define, Jack St. Malo and other projects. Additionally, we received an unfavorable arbitration award related to the In Amenas project resulting in a $15 million decrease to job income in the first quarter of 2009 which did not recur in 2010.

Job income in our Oil & Gas Operations in the first six months of 2010 decreased by $15 million over the same quarter of the prior year. The decrease in Oil & Gas Operations job income includes approximately $20 million of decrease related to various projects that were either completed in 2009 or nearing completion in the end of the second quarter of 2010. Job income further decreased by approximately $9 million as a result of legal fees and the unfavorable settlement of several issues related to a completed project. Partially offsetting these decreases was an unfavorable arbitration award related to the In Amenas project resulting in a $15 million decrease to job income in the first quarter of 2009 which did not recur in 2010.

Downstream. Downstream revenue in the first six months of 2010 increased by $53 million primarily due to several petrochemical projects including the Ras Tanura, Shaybah, Yanbu and Sonangol projects which increased approximately $109 million in the aggregate as a result of increased activity over the prior year. These increases in revenues were partially offset by lower revenues on several chemical projects in North America and other refining projects as they were either completed or nearing completion.

Downstream job income in the first six months of 2010 increased by approximately $24 million as compared to the same period of the prior year. The increase was primarily driven by increased activity on the Sonangol and Ras Tanura projects which contributed $25 million to the increase. Additionally, Downstream job income in the first six months of 2009 included $16 million in charges on our EBIC ammonia project due to additional costs related to the commissioning and start up of the plant which further contributed to the improvement in job income during the first six months of 2010. Partially offsetting these increases in job income was a charge of approximately $9 million related to an accounts receivable reserve adjustment recorded in the second quarter of 2010 as well as decreases on several other projects that were completed or nearing completion.

Index

Technology. Technology revenues and job income in the first six months of 2010 increased $22 and $9 million, respectively, primarily due to the progress achieved on a number of new projects including a grassroots ammonia and urea project in Turkmenistan, two ammonia equipment projects in India, petrochemical plants in Korea and a refining project in Angola. These new projects contributed approximately $33 million to the increase in Technology revenues and approximately $19 million to the increase in Technology job income in the first six months of 2010. Partially offsetting these increases were decreases in revenue and job income associated with the completion of an ammonia revamp project in India and two ammonia projects in Venezuela.

Infrastructure, Government and Power (“IGP”) Business Group

North America Government and Defense (“NAGD”). Revenue from our NAGD Operations decreased approximately $1.0 billion in the first six months of 2010 over the same period in the prior year. The decrease in NGAD revenue includes a $944 million decline resulting from an overall reduction in volume for U.S. military support activities primarily in Iraq under our LogCAP III contract. The lower volume is primarily due to the continued reductions in staff and personnel on the project as combat troop levels declined. We expect to continue providing services on certain task orders through the second half of 2010. Although the decreases in revenue on the LogCAP III project have been partially offset by a task order on the LogCAP IV contract, we expect our overall volume of work to continue to decrease in Iraq throughout the remainder of 2010. Also contributing to the decrease in NAGD revenue is $61 million less revenue as a result of lower volumes of work under the CENTCOM project.

Job income from our NAGD Operations decreased by approximately $15 million primarily as a result of a decrease in job income on the LogCAP III and CENTCOM projects. Job income on the LogCAP III project decreased by approximately $32 million as a result of lower volumes and higher charges for potentially unallowable costs but were partially offset by an increase in award fees during the first six months of 2010. Award fees on the LogCAP III project in the first six months of 2010 were approximately $22 million higher as compared to the same period of the prior year. Prior to the first quarter of 2010, we accrued award fees based on the estimated amounts to be awarded. However, as a result of the U.S. Army’s Iraq Award Fee Evaluation Board decision in February 2010 to award zero award fees for certain prior periods of performance, we concluded that we could no longer estimate the amount of fees to be awarded. Therefore, we ceased accruing any further award fees until we can reliably estimate fees to be awarded in the future or when such fees are actually awarded. Subsequently, in May 2010, we received an award fee of approximately $60 million which was recorded as an increase to revenue. Additionally, job income on the CENTCOM project decreased by approximately $10 million as a result of lower volumes of work.

International Government and Defense (“IGD”). Revenue from our IGD Operations increased approximately $60 million and job income increased approximately $5 in the first six months of 2010 compared the same period in the prior year. The increase in revenue was primarily related to the increasing presence of troops in Afghanistan where we provide contingency logistics, operations and maintenance and other services to the U.K. MoD under the TDA, CONLOG and NAMSA projects. Job income in the first six months of 2010 increased due to higher construction margins on the Allenby & Connaught project as well as higher volume of services for the TDA, CONLOG and other U.K. MoD projects. These increases were partially offset due to decreases in job income on the Tier 3 Basra project which was completed in 2009.

Infrastructure and Minerals (“I&M”). Revenue from our I&M Operations decreased approximately $35 million in the first six months of 2010 over the same period in the prior year due to lower overall activity on several projects including Southern Regional Water Pipeline and Hope Downs South Minerals projects in Australia, the Scottish Water project in the U.K. and the Yas Island Development project in Abu Dhabi. These projects have either been completed prior to the second quarter of 2010 or scaled down as a result of the global economic conditions. Additionally, new project awards have been either delayed or canceled, further contributing to the decrease. Job income from our I&M Operations decreased in the first six months of 2010 by approximately $11 million primarily as a result of the overall decrease in project activity and new project awards.

Power and Industrial (“P&I”). Revenue from our P&I Operations decreased approximately $14 million in the first six months of 2010 over the same period in the prior year largely as a result of the completion of the Georgia Power and Proctor & Gamble projects. These decreases were largely offset by increased volume from construction mobilization on the new waste-to-energy project in Florida and increased volume on several other smaller projects. Job income from our P&I Operations increased in the first six months of 2010 by $9 million primarily due to change orders at the Georgia Power project as well as mobilization of the waste-to-energy project in Florida.

Index

Services

Services revenues in the first six months of 2010 decreased by $106 million as compared to the first six months of 2009. Approximately $150 million of the decrease occurred in our Building Group due to lower volume. Although the building group was recently awarded several new projects including the Boeing 787 Assembly Facility and Alabama Children’s Hospital, these projects did not significantly contribute to revenues in the first quarter of 2010 as they are executed through joint ventures that we do not control and are thus accounted for under the equity method of accounting. Additionally, revenues in our U.S. Construction Group declined $17 million primarily due to the completion of the Conoco Phillips Borger and ExxonMobil Flare Gas projects in 2009. Partially offsetting these decreases in revenues were increases of approximately $51 million in our Canadian Operations largely resulting from higher levels of activity on the Shell AOSP project.

Job income increased by approximately $3 million in the first quarter of 2010 over the first quarter of 2009. Increases in job income resulting from the increased activity on the Shell AOSP and various U.S. Construction projects were largely offset by slowdowns in our maintenance projects in Europe which are tied to the pulp and paper markets.

Ventures

Ventures revenue was $28 million and job income was $17 million in the first six months of 2010 as compared to revenue of $11 million and job income of $10 million in the first six months of 2009. The increase in revenue is primarily attributable to the consolidation of Fasttrax Limited, which is the primary contracting entity with the MoD in a project that owns and operates heavy equipment transport vehicles for the U.K. military. This variable interest entity, in which we have a 50% ownership interest, was previously accounted for using the equity method of accounting. Effective January 1, 2010, we determined we were the primary beneficiary pursuant to the adoption of in FASB ASC 810 – Consolidation in the first quarter of 2010. Ventures job income increased during the first quarter of 2010 primarily due to the improved performance of the EBIC ammonia plant project and Allenby & Connaught projects as well as the consolidation of Fasttrax Ltd.

Labor cost absorption. Labor cost absorption expense was zero for the first six months of 2010 and was $2 million in the first six months of 2009. Labor cost absorption represents costs incurred by our central labor and resource groups (above) or under the amounts charged to the operating business units. Labor cost absorption expense decreased in the first six months of 2010 primarily due to higher chargeability and utilization in several of our engineering offices as well as higher incentive compensation which was partially offset by lower headcount. Partially offsetting these increases were lower costs due to closure of one of our offices in Lagos as well as lower costs under our 2009 incentive compensation plan.

Index

Allocation of Services Business Unit to IGP and Hydrocarbons

	Six Months Ended June 30, 2010
	Business Unit Revenue		Allocation of Services			Total Allocated Revenue
Hydrocarbons business group:
Gas Monetization	$	1,383	$	—		$	1,383
Oil & Gas		188		179			367
Downstream		290		286			576
Technology		65		—			65
Total Hydrocarbons business group revenue		1,926		465			2,391

Infrastructure, Government and Power (“IGP”):
North America Government and Defense		1,936		33			1,969
International Government and Defense		197		—			197
Infrastructure and Minerals		137		—			137
Power and Industrial		201		369			570
Total IGP business group revenue		2,471		402			2,873

Services		867		(867	)		—
Other		38		—			38
Total KBR Revenue	$	5,302	$	—		$	5,302

	Six Months Ended June 30, 2009
	Business Unit Revenue		Allocation of Services			Total Allocated Revenue
Hydrocarbons business group:
Gas Monetization	$	1,335	$	—		$	1,335
Oil & Gas		202		121			323
Downstream		237		284			521
Technology		43		—			43
Total Hydrocarbons business group revenue		1,817		405			2,222

Infrastructure, Government and Power (“IGP”):
North America Government and Defense		2,957		27			2,984
International Government and Defense		137		—			137
Infrastructure and Minerals		172		—			172
Power and Industrial		215		541			756
Total IGP business group revenue		3,481		568			4,049

Services		973		(973	)		—
Other		30		—			30
Total KBR Revenue	$	6,301	$	—		$	6,301

Index

Non-operating items

Net interest expense was $9 million in the first six months of 2010 and net interest income was $1 million in the first six months of 2009. Interest expense increased for the first six months primarily as a result of increased commitment fees paid under the terms of our new credit facility, increased rates associated with outstanding performance-related and financial-related issued letters of credit, and fees paid to Halliburton for guarantees provided to us for various financial commitments. Additionally, interest expense recognized in the second quarter of 2010 on non-recourse project-finance debt was $3 million higher as a result of the consolidation of Faxttrax Limited effective January 1, 2010. Interest income earned on our invested cash remained relatively flat for the first six months of 2010 compared to the first six months of 2009 as a result of the current economic conditions.

We had foreign currency losses of $5 million in the first six months of 2010 and foreign currency gains of $1 million in the first six months of 2009. Foreign currency losses in the first six months of 2010 were primarily due to the weakening Euro and from currencies with no hedge market such as the Algerian Dinar. The foreign currency gains in the first six months of 2009 primarily resulted from the remeasurement of monetary assets and liabilities in foreign jurisdictions as a result of the strengthening of the U.S. dollar against certain foreign currencies in the first quarter of 2009 including the Euro, Algerian dinar and Japanese yen. Some of these positions were not fully hedged.

Provision for income taxes was $103 million in the first six months of 2010 and $104 million in the first six months of 2009. Our effective tax rate was approximately 36% for the six months ended June 30, 2010 and 37% for the six months ended June 30, 2009. Our effective tax rate for the first six months of 2010 was higher than our statutory rate of 35% primarily due to discrete items charged to income tax expense related to increased tax accruals due to several items including Subpart F income and true-up of prior year foreign taxes. Our effective tax rate for the first six months of 2009 was higher than our statutory rate of 35% primarily due to discrete items charged to income tax expense from the true-up of prior year foreign and domestic taxes.

Backlog

Backlog represents the dollar amount of revenue we expect to realize in the future as a result of performing work on contracts awarded and in progress. We generally include total expected revenue in backlog when a contract is awarded and/or the scope is definitized. For long-term contracts, the amount included in backlog is limited to five years. In many instances, arrangements included in backlog are complex, nonrepetitive in nature, and may fluctuate depending on expected revenue and timing. Where contract duration is indefinite, projects included in backlog are limited to the estimated amount of expected revenue within the following twelve months. Certain contracts provide maximum dollar limits, with actual authorization to perform work under the contract being agreed upon on a periodic basis with the customer. In these arrangements, only the amounts authorized are included in backlog. For projects where we act solely in a project management capacity, we only include our management fee revenue of each project in backlog.

For our projects related to unconsolidated joint ventures, we have included in the table below our percentage ownership of the joint venture’s revenue in backlog. However, because these projects are accounted for under the equity method, only our share of future earnings from these projects will be recorded in our revenue. Our backlog for projects related to unconsolidated joint ventures totaled $1.9 billion at June 30, 2010 and $2.1 billion at December 31, 2009. We also consolidate joint ventures which are majority-owned and controlled or are variable interest entities in which we are the primary beneficiary. Our backlog included in the table below for projects related to consolidated joint ventures with noncontrolling interests includes 100% of the backlog associated with those joint ventures and totaled $4.1 billion at June 30, 2010 and $4.6 billion at December 31, 2009.

Index

Backlog(1)

(in millions)

	June 30,		December 31,
	2010		2009
Hydrocarbons:
Gas Monetization	$	5,899	$	6,976
Oil & Gas		228		109
Downstream		425		535
Technology		194		154
Total Hydrocarbons backlog		6,746		7,774
Infrastructure, Government and Power (“IGP”):
North America Government and Defense		987		1,341
International Government and Defense		1,231		1,427
Infrastructure and Minerals		133		167
Power and Industrial		239		338
Total IGP backlog		2,590		3,273
Services		2,307		2,302
Ventures		780		749
Total backlog for continuing operations	$	12,423	$	14,098

________________________

(1)	All backlog is attributable to firm orders as of June 30, 2010 and December 31, 2009. Backlog attributable to unfunded government orders was $154 million at June 30, 2010 and $326 million as of December 31, 2009.

We estimate that as of June 30, 2010, 49% of our backlog will be complete within one year. As of June 30, 2010, approximately 21% of our backlog was attributable to fixed-price contracts and 79% was attributable to cost-reimbursable contracts. For contracts that contain both fixed-price and cost-reimbursable components, we classify the components as either fixed-price or cost-reimbursable according to the composition of the contract except for smaller contracts where we characterize the entire contract based on the predominant component.

Hydrocarbons business group backlog declined approximately $1.0 billion, primarily because of a decline in Gas Monetization business unit backlog of approximately $1.1 billion primarily due to work performed on the Gorgon, Skikda, Escravos and other projects and with no new significant awards in the first six months of 2010. Also contributing to the decline in Hydrocarbons business group backlog was a decline in the Downstream business unit backlog of approximately $148 million primarily related to work performed on our Ras Tanura, Sonangol, Yanbu, Saudi Kayan and other projects. These declines were partially offset by new awards of $238 million in our Oil & Gas and Technology business.

Backlog in our IGP business group decreased by $683 million primarily as a result of the net work-off on existing projects of approximately $775 million, that were partially offset by new awards of $224 million primarily in our International and North America Government and Defense operations. Work performed in our North America Government and Defense operations was approximately $496 million in the first six months primarily related to our LogCAP III and IV project, DOCCC, Alaska JOC and other support projects, partially offset by new awards of $100 million on our LogCAP IV project. In our International Government and Defense operations we had work performed of $279 million primarily related to the Allenby and Connaught project, Conlog Afghanistan ISP and TDA, which was partially offset by new awards in 2010, primarily from the U.K. MoD.

Backlog in Services remained relatively flat at $2.3 billion. Major awards in Services included projects in our Building Group product line such as the Boeing 787 Assembly Facility and Alabama Children’s Hospital projects as well as the DuPont project in our Industrial Services product line.

Index

Liquidity and Capital Resources

Cash and equivalents totaled $1.2 billion at June 30, 2010 and $941 million at December 31, 2009, which included $267 million and $236 million, respectively, of cash related to contracts in progress as well as cash held by our joint ventures that we consolidate for accounting purposes. Joint venture cash balances are limited to joint venture activities and are not available for use on other projects, general cash needs or distributions to us without approval of the board of directors of the respective joint ventures. We expect to use the cash on these projects to pay project costs.

As of June 30, 2010, we had restricted cash of $23 million related to the amounts held in deposit with certain banks to collateralize standby letters of credit, of which $14 million is included in “Other current assets” and $9 million is included in “Other assets” in the accompanying condensed consolidated financial statements.

Revolving Credit Facility

On November 3, 2009, we entered into a new syndicated, unsecured $1.1 billion three-year revolving credit agreement (the “Revolving Credit Facility”), with Citibank, N.A., as agent, and a group of banks and institutional lenders replacing the Prior Revolving Credit Facility, which was terminated at the same time as the closing of the Revolving Credit Facility. The Revolving Credit Facility may be used for working capital and letters of credit for general corporate purposes which expires in November 2012. While there is no sublimit for letters of credit under this facility, letters of credit fronting commitments that totaled $830 million at December 31, 2009 have been expanded to $880 million in January 2010. Amounts drawn under the Revolving Credit Facility will bear interest at variable rates based either on the London interbank offered rate plus 3%, or a base rate plus 2%, with the base rate being equal to the highest of reference bank’s publicly announced base rate, the Federal Funds Rate plus 0.5%, or the London interbank offered rate plus 1%. Fees on letters of credit issued under the Revolving Credit Facility are 1.5% for performance and commercial letters of credit and 3% for all others. We are also charged an issuance fee of 0.05% for the issuance of a letter of credit, a per annum commitment fee of 0.625% for any unused portion of the Revolving Credit Facility, and a per annum fronting commitment fee of 0.25%. As of June 30, 2010, there were no borrowings and $326 million in letters of credit issued and outstanding under the Revolving Credit Facility.

The Revolving Credit Facility includes financial covenants requiring maintenance of a ratio of consolidated debt to consolidated EBITDA of less than 3.5 to 1 and a minimum consolidated net worth of $2 billion plus 50% of consolidated net income for each quarter ending after September 30, 2009 plus 100% of any increase in shareholders equity attributable to the sale of equity securities. At June 30, 2010, we were in compliance with these ratios and other covenants mentioned above.

The Revolving Credit Facility also contains a number of covenants restricting, among other things, our ability to incur additional liens and sales of our assets, as well as limiting the amount of investments we can make. The Revolving Credit Facility also permits us, among other things, to declare and pay shareholder dividends and/or engage in equity repurchases not to exceed $400 million in the aggregate during the term of the facility and to incur indebtedness in respect of purchase money obligations, capitalized leases and refinancing or renewals secured by liens upon or in property acquired, constructed or improved in an aggregate principal amount not to exceed $200 million. Our subsidiaries may incur unsecured indebtedness not to exceed $100 million in aggregate outstanding principal amount at any time.

Nonrecourse Project Finance Debt

In 2001, Fasttrax Limited, a joint venture in which we indirectly own a 50% equity interest with an unrelated partner, was awarded a contract with the U.K. MoD to provide a fleet of 92 heavy equipment transporters (“HETs”) to the British Army. Under the terms of the arrangement, Fasttrax Limited operates and maintains the HET fleet for a term of 22 years. The purchase of the HETs by the joint venture was financed through a series bonds secured by the assets of Fasttrax Limited totaling approximately £84.9 million and are non-recourse to KBR and its partner of which £12.2 million provided equity bridge financing. The bridge financing was replaced in 2005 with combined equity capital contributions and subordinated loans from the joint venture partners. The bonds are guaranteed by Ambac Assurance UK Ltd under a policy that guarantees the schedule of the principle and interest payments to the bond trustee in the event of non-payment by Fasttrax Limited.

Index

The guaranteed secured bonds were issued in two classes consisting of Class A 3.5% Index Linked Bonds in the amount of £56 million and Class B 5.9% Fixed Rate Bonds in the amount of £16.7 million. Payments on both classes of bonds commenced in March 2005 and are due in semi-annual installments over the term of the bonds which end in 2021. Subordinated notes payable to our 50% partner initially bear interest at 11.25% increasing to16% over the term of the note through 2025. Payments on the subordinated debt commenced in March 2006 and are due in semi-annual installments over the term of the note.

Since the inception of the project, we accounted for our investment in the project entity using the equity method of accounting. As a result of the adoption of Accounting Standards Update No. 2009-17 – Consolidation (Topic 810) “Improvements to Financial Reporting by Enterprises with Variable Interest Entities”, effective January 1, 2010 we concluded that we are the primary beneficiary of Fasttrax Limited because we control the activities that most significantly impact the economic performance of the entity. We have applied the requirements of FASB ASC 810 on a prospective basis from the date of adoption. As such, our condensed consolidated financial statements for the first six months of 2010 include the accounts of Fasttrax Limited and accordingly, the cash and equivalents, property, plant and equipment, and the non-recourse project financing debt. The secured bonds are an obligation of Fasttrax Limited and will never be a debt obligation of KBR because they are non-recourse to the joint venture partners. Accordingly, in the event of a default on the term loan, the lenders may only look to the resources of Fasttrax Limited for repayment.

Cashflow Activities

	For the Six Months Ended
	2010			2009

Cash flows provided by (used in) operating activities	$	432		$	(8	)
Cash flows used in investing activities		(56	)		(13	)
Cash flows used in financing activities		(83	)		(59	)
Effect of exchange rate changes on cash		(21	)		12
Increase (decrease) in cash and equivalents	$	272		$	(68	)
Cash increase due to consolidation of a variable interest entity		22			—
Net increase (decrease) in cash and equivalents	$	294		$	(68	)

Operating activities. Cash provided by operations was $432 million in the first six months of 2010, compared to cash used by operations of $8 million in the first six months of 2009. Cash provided by operations during the first six months of 2010 was primarily impacted by overall earnings as well as improvements in cash receipts on certain projects in our Gas Monetization, Downstream and International Government and Defense business units. Also contributing to the increase in cash provided by operations was the decline of approximately $96 million in working capital requirements for our LogCAP project including the receipt of $60 million of award fees during the second quarter of 2010. Additionally, cash held by joint ventures that we consolidate for accounting purposes increased approximately $30 million during the first six months of 2010.

Cash used in operations was $8 million in the first six months of 2009. Cash held by our joint venture projects that we consolidate for accounting purposes increased from $175 million at December 31, 2008 to $225 million at June 30, 2009. Joint venture cash balances are limited to joint venture activities and are not available for other projects, general cash needs, or distribution to us without approval of the board of directors of the respective joint ventures. Additionally, cash increased by approximately due to $20 million in distributions and repayments of advances we received from our unconsolidated joint ventures, which are accounted for using the equity method of accounting. Partially offsetting these increases were decreases due to higher working capital requirements on our LogCAP and other projects during the first six months of 2009.

Investing activities. Cash used in investing activities for the first six months of 2010 totaled $56 million compared to $13 million during the first six months of 2009. During the first six months of 2010, we paid $20 million for the exclusive right to certain technology under a 25-year licensing arrangement. Cash used for capital expenditures were $19 million and $16 million for the first six months of 2010 and 2009, respectively. Additionally, we financed approximately $19 million for the purchase of computer software for internal use during the second quarter of 2010. In the second quarter of 2010 we acquired Energo Engineering for approximately $16 million in cash, subject to an escrowed holdback amount of $6 million to secure working capital adjustments. The increase in capital expenditures was primarily related to increased corporate infrastructure spending and leasehold improvements. In the first six months of 2010, we made a $7 million investment in an equity method joint venture associated with our lease extension of our corporate headquarters.

Index

Financing activities. Cash used in financing activities for the first six months of 2010 totaled $83 million and included $58 million of payments to repurchase approximately 2.6 million shares of our common stock, $16 million related to dividend payments to shareholders and $30 million related to distributions to noncontrolling shareholders of several of our consolidated joint ventures. These payments were partially offset by the return of approximately $24 million of collateralized cash related to our standby letters of credit. Cash used in financing activities was $59 million for the first six months of 2009 and included $21 million of payments to reacquire 1.5 million shares of our common stock and $24 million related to dividend payments to our shareholders and to noncontrolling shareholders of several of our consolidated joint ventures. During the second quarter of 2009, we cash collateralized $14 million of our standby letters of credit in accordance with certain agreements.

Future sources of cash. Future sources of cash include cash flows from operations, including cash advance payments from our customers, and borrowings under our Revolving Credit Facility. The Revolving Credit Facility is available for cash advances required for working capital and letters of credit to support our operations. However, to meet our short- and long-term liquidity requirements, we will primarily look to our existing cash balances and cash generated from future operating activities.

Future uses of cash. Future uses of cash will primarily relate to working capital requirements for our operations. In addition, we will use cash to fund capital expenditures, pension obligations, operating leases, cash dividends, share repurchases and various other obligations as they arise. The capital expenditures budget for 2010 is consistent with our prior year capital expenditures and primarily relates to information technology, real estate and equipment/facilities to be used in our business units. From July 1, 2010 through July 28, 2010, we repurchased approximately 1.9 million shares of KBR stock for approximately $40 million under our share repurchase program.

On May 20, 2010, our Board of Directors declared a quarterly cash dividend of $0.05 per share of common stock payable on July 15, 2010 to shareholders of record on June 15, 2010. The dividend payment is approximately $8 million and is included in other current liabilities as of June 30, 2010. Any future dividend declarations will be at the discretion of our Board of Directors.

Off balance sheet arrangements

Letters of credit, surety bonds and bank guarantees. In connection with certain projects, we are required to provide letters of credit or surety bonds to our customers. Letters of credit are provided to customers in the ordinary course of business to guarantee advance payments from certain customers, support future joint venture funding commitments and to provide performance and completion guarantees on engineering and construction contracts. We have $1.7 billion in committed and uncommitted lines of credit to support letters of credit and as of June 30, 2010, and we had utilized $507 million of our credit capacity. We have an additional $197 million in letters of credit issued and outstanding under various other facilities that are unconditionally and irrevocably guaranteed by Halliburton. Surety bonds are also posted under the terms of certain contracts primarily related to state and local government projects to guarantee our performance.

The $507 million in letters of credit outstanding on KBR lines of credit was comprised of $326 million issued under our Revolving Credit Facility and $181 million issued under uncommitted bank lines at June 30, 2010. Of the total letters of credit outstanding, $34 million of the letters of credit have terms that could entitle a bank to require additional cash collateralization on demand. Approximately $208 million of the $326 million letters of credit issued under our Revolving Credit Facility have expiry dates close to or beyond the maturity date of the facility. Under the terms of the Revolving Credit Facility, if the original maturity date of November 2, 2012 is not extended then the issuing banks may require that we provide cash collateral for these extended letters of credit no later than 95 days prior to the original maturity date. As the need arises, future projects will be supported by letters of credit issued under our Revolving Credit Facility or arranged on a bilateral basis. We believe we have adequate letter of credit capacity under our existing Revolving Credit Facility and bilateral lines of credit to support our operations for the next twelve months.

Other obligations. We had commitments to provide funds to our privately financed and other projects of $47 million as of June 30, 2010 primarily related to future equity funding on our Allenby and Connaught project. Commitments to fund these projects are supported by letters of credit as described above. At June 30, 2010, approximately $19 million of the $47 million in commitments will become due within one year.

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We have an obligation to fund estimated losses on our uncompleted contracts which totaled $31 million at June 30, 2010. Approximately $27 million of this amount relates to our Escravos project, the majority of which is expected to be funded in 2010.

We executed two lease amendments for office space in two separate high-rise office buildings in Houston, Texas for the purpose of significantly expanding our current leased office space and to extend the original term of these leases to June 30, 2030. As a result we expect our estimated total rentals on all noncancelable operating leases to be as follows: $56 million in 2010; $50 million in 2011, $45 million in 2012; $40 million in 2013; $37 million in 2014 and $318 thereafter.

Other factors affecting liquidity

Government claims. Unapproved claims relate to contracts where our costs have exceeded the customer’s funded value of the task order. Our unapproved claims for costs incurred under various government contracts totaled $101 million at June 30, 2010 and $113 million at December 31, 2009. The unapproved claims at June 30, 2010 include approximately $59 million largely resulting from the de-obligation of 2004 funding on certain task orders that were also subject to Form 1 notices relating to certain DCAA audit issues primarily related to dining facilities. We believe such disputed costs will be resolved in our favor at which time the customer will be required to obligate funds from the year in which resolution occurs. The unapproved claims outstanding at June 30, 2010 and December 31, 2009 are considered to be probable of collection and have been recognized as revenue.

Liquidated damages. Many of our engineering and construction contracts have milestone due dates that must be met or we may be subject to penalties for liquidated damages if claims are asserted and we were responsible for the delays. These generally relate to specified activities that must be met within a project by a set contractual date or achievement of a specified level of output or throughput of a plant we construct. Each contract defines the conditions under which a customer may make a claim for liquidated damages. However, in some instances, liquidated damages are not asserted by the customer, but the potential to do so is used in negotiating claims and closing out the contract.

We had not accrued for liquidated damages related to several projects, including the exposure described in the above paragraph, totaling $19 million at June 30, 2010 (including amounts related to our share of unconsolidated subsidiaries), that we could incur based upon completing the projects as forecasted.

Halliburton indemnities. Halliburton has agreed to indemnify us and certain of our greater than 50%-owned subsidiaries for fines or other monetary penalties or direct monetary damages, including disgorgement, as a result of certain claims made or assessed against us by U.S. and certain foreign governmental authorities or a settlement thereof, relating to investigations under the FCPA or analogous applicable foreign statutes related investigations with respect to the construction and subsequent expansion by TSKJ of a natural gas liquefaction complex in Nigeria. Halliburton has also agreed to indemnify us for out-of-pocket cash costs and expenses, or cash settlement or cash arbitration awards in lieu thereof, we may incur as a result of the replacement of certain subsea flow-line bolts installed in connection with the Barracuda-Caratinga project. See Note 7 to our condensed consolidated financial statements for further discussion.

In February 2009, one of our subsidiaries plead guilty to violating and conspiring to violate the FCPA. In accordance with the terms of the settlement and under the terms of the Halliburton indemnity, Halliburton paid $95 million in the first six months of 2010 and $322 million in the first six months of 2009 on our behalf for penalties resulting from the FCPA violations, which have been reflected in the accompanying statement of cash flows as noncash operating activities.

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Legal Proceedings

Information related to various commitments and contingencies is described in Notes 6 and 7 to the condensed consolidated financial statements.

Environmental Regulation

New Accounting Standards

A reporting entity should disclose separately the amounts of significant transfers in and out of Level 1 and Level 2 fair value measurements and describe the reasons for the transfers; and

In the reconciliation for fair value measurements using significant unobservable inputs, a reporting entity should present separately information about purchases, sales, issuances, and settlements.

In addition, ASU 2010-06 clarifies the requirements of the following existing disclosures:

A reporting entity should provide disclosures about the valuation techniques and inputs used to measure fair value for both recurring and nonrecurring fair value measurements.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

We are exposed to financial instrument market risk from changes in foreign currency exchange rates and interest rates. 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 Rules 13a-15 and 15d-15 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), 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 June 30, 2010 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.

During the most recent fiscal quarter, there have been no changes in our internal control over financial reporting that have materially affected, or are 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 Notes 6 and 7 to the condensed consolidated financial statements and in Managements’ Discussion and Analysis of Financial Condition and Results of Operations – Legal Proceedings and the information discussed therein is incorporated herein.

Item 1A. Risk Factors

There are no material changes from the risk factors previously disclosed in Part I, Item 1A in our Annual Report on Form 10-K, which is incorporated herein by reference, for the year ended December 31, 2009.

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

(a)

None.

(b)

None.

(c)

On June 8, 2010, we initiated a Board of Directors authorized share repurchase program pursuant to which we intend to repurchase up to 10 million of our outstanding common shares in the open market or privately negotiated transactions to reduce and maintain, over time, our outstanding shares at approximately 150 million shares. We entered into an agreement with an agent to conduct a designated portion of the repurchase program in accordance with Rules 10b-18 and 10b5-1 under the Securities Exchange Act of 1934. The following is a summary of share repurchases of our common stock during the three months ended June 30, 2010.

Purchase Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Number of Shares that May Yet Be Purchased Under the Plans or Programs
April 1 – 27, 2010
Employee Transactions (a)	25,123	$	22.43	—	—
May 2 –30, 2010
Employee Transactions (a)	3,362	$	21.26	—	—
June 8 – 30, 2010
Repurchase Program	2,500,200	$	22.37	2,500,200	7,499,800
Employee Transactions (a)	3,985	$	22.52	—	—
Total
Repurchase Program	2,500,200	$	22.37	2,500,200	7,499,800
Employee Transactions (a)	32,470	$	22.32	—	—

(a)	Reflects shares acquired from employees in connection with the settlement of income tax and related benefit withholding obligations arising from vesting in restricted stock units.

Item 3. Defaults Upon Senior Securities

None.

Item 4. (Removed and Reserved)

Item 5. Other Information

None.

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Item 6. Exhibits

Exhibit Number		Description
3.1		KBR Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to KBR’s registration statement on Form S-1; Registration No. 333-133302)

3.2		Amended and Restated Bylaws of KBR, Inc. (incorporated by reference to Exhibit 3.1 to KBR’s Form 10-Q for the period ended June 30, 2007; File No. 1-33146)

4.1		Form of specimen KBR common stock certificate (incorporated by reference to Exhibit 4.1 to KBR’s registration statement on Form S-1; Registration No. 333-133302)

*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.

***101.INS		XBRL Instance Document

***101.SCH		XBRL Taxonomy Extension Schema Document

***101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document

***101.LAB		XBRL Taxonomy Extension Labels Linkbase Document

***101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document

***101.DEF		XBRL Taxonomy Extension Definition Linkbase Document

*		Filed with this Form 10-Q

**		Furnished with this Form 10-Q

***		In accordance with Rule 406T of Regulation S-T, the XBRL related information in Exhibit 101 to this Quarterly Report on Form 10-Q shall not be deemed to be “filed” for purposes of Section 18 of the Exchange Act, or otherwise subject to the liability of that section, and shall not be part of any registration statement or other document filed under the Securities Act or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.

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Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

KBR, INC.

/s/ Susan K. Carter		/s/ John W. Gann, Jr.
Susan K. Carter		John W. Gann, Jr.
Senior Vice President and Chief Financial Officer		Vice President and Chief Accounting Officer

Date: July 29, 2010