10-Q 1 hal_6302012-10q.htm HAL_6.30.2012-10Q
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, 2012

OR

[   ]   Transition Report Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
For the transition period from _____ to _____

Commission File Number 001-03492

HALLIBURTON COMPANY

(a Delaware corporation)
75-2677995

3000 North Sam Houston Parkway East
Houston, Texas  77032
(Address of Principal Executive Offices)

Telephone Number – Area Code (281) 871-2699

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

Yes
[X]
No
[   ]
 
Indicate by check mark whether the registrant 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
[   ]

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

 
Large accelerated filer
[X]
Accelerated filer
[   ]
 
Non-accelerated filer
[   ]
Smaller reporting company
[   ]

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

Yes
[   ]
No
[X]

As of July 20, 2012, 927,750,281 shares of Halliburton Company common stock, $2.50 par value per share, were outstanding.



HALLIBURTON COMPANY

Index

 
 
Page No.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 



PART I. FINANCIAL INFORMATION
Item 1. Financial Statements

HALLIBURTON COMPANY
Condensed Consolidated Statements of Operations
(Unaudited)
 
 
Three Months Ended
June 30
 
Six Months Ended
June 30
Millions of dollars and shares except per share data
 
2012
 
2011
 
2012
 
2011
Revenue:
 
 
 
 
 
 
 
 
Services
 
$
5,670

 
$
4,727

 
$
11,094

 
$
8,918

Product sales
 
1,564

 
1,208

 
3,008

 
2,299

Total revenue
 
7,234

 
5,935

 
14,102

 
11,217

Operating costs and expenses:
 
 

 
 

 
 

 
 

Cost of services
 
4,638

 
3,659

 
9,171

 
7,087

Cost of sales
 
1,328

 
1,050

 
2,572

 
2,020

General and administrative
 
67

 
65

 
135

 
135

Total operating costs and expenses
 
6,033

 
4,774

 
11,878

 
9,242

Operating income
 
1,201

 
1,161

 
2,224

 
1,975

Interest expense, net of interest income of $2, $2, $4, and $3
 
(80
)
 
(63
)
 
(154
)
 
(132
)
Other, net
 
(17
)
 
(5
)
 
(24
)
 
(9
)
Income from continuing operations before income taxes
 
1,104

 
1,093

 
2,046

 
1,834

Provision for income taxes
 
(357
)
 
(352
)
 
(661
)
 
(581
)
Income from continuing operations
 
747

 
741

 
1,385

 
1,253

Income (loss) from discontinued operations, net of income tax (provision) benefit of $(3), $1, $2, and $1
 
(8
)
 

 
(16
)
 
(1
)
Net income
 
$
739

 
$
741

 
$
1,369

 
$
1,252

Noncontrolling interest in net income of subsidiaries
 
(2
)
 
(2
)
 
(5
)
 
(2
)
Net income attributable to company
 
$
737

 
$
739

 
$
1,364

 
$
1,250

Amounts attributable to company shareholders:
 
 

 
 

 
 

 
 

Income from continuing operations
 
$
745

 
$
739

 
$
1,380

 
$
1,251

Loss from discontinued operations, net
 
(8
)
 

 
(16
)
 
(1
)
Net income attributable to company
 
$
737

 
$
739

 
$
1,364

 
$
1,250

Basic income per share attributable to company shareholders:
 
 

 
 

 
 

 
 

Income from continuing operations
 
$
0.81

 
$
0.81

 
$
1.50

 
$
1.37

Loss from discontinued operations, net
 
(0.01
)
 

 
(0.02
)
 

Net income per share
 
$
0.80

 
$
0.81

 
$
1.48

 
$
1.37

Diluted income per share attributable to company shareholders:
 
 

 
 

 
 

 
 

Income from continuing operations
 
$
0.80

 
$
0.80

 
$
1.49

 
$
1.36

Loss from discontinued operations, net
 
(0.01
)
 

 
(0.02
)
 

Net income per share
 
$
0.79

 
$
0.80

 
$
1.47

 
$
1.36

Cash dividends per share
 
$
0.09

 
$
0.09

 
$
0.18

 
$
0.18

Basic weighted average common shares outstanding
 
924

 
916

 
923

 
915

Diluted weighted average common shares outstanding
 
926

 
921

 
926

 
920

     See notes to condensed consolidated financial statements.
 
 
 
 
 
 
 
 

1


HALLIBURTON COMPANY
Condensed Consolidated Statements of Comprehensive Income
(Unaudited)

 
 
Three Months Ended
June 30
 
Six Months Ended
June 30
Millions of dollars
 
2012
 
2011
 
2012
 
2011
Net income
 
$
739

 
$
741

 
$
1,369

 
$
1,252

Other comprehensive income, net of income taxes:
 
 

 
 

 
 

 
 

Defined benefit and other postretirement plans adjustments
 
$
6

 
$
(1
)
 
$
14

 
$
(1
)
Other
 
(1
)
 
2

 
(2
)
 
4

Other comprehensive income, net of income taxes
 
5

 
1

 
12

 
3

Comprehensive income
 
$
744

 
$
742

 
$
1,381

 
$
1,255

Comprehensive income attributable to noncontrolling interest
 
(2
)
 
(2
)
 
(5
)
 
(2
)
Comprehensive income attributable to company shareholders
 
$
742

 
$
740

 
$
1,376

 
$
1,253

     See notes to condensed consolidated financial statements.
 
 
 
 
 
 
 
 


2


HALLIBURTON COMPANY
Condensed Consolidated Balance Sheets

 
 
June 30,
2012
 
December 31,
2011
Millions of dollars and shares except per share data
 
(Unaudited)
 
 
Assets
Current assets:
 
 
 
 
Cash and equivalents
 
$
2,172

 
$
2,698

Receivables (less allowance for bad debts of $117 and $137)
 
5,674

 
5,084

Inventories
 
3,297

 
2,570

Other current assets
 
1,391

 
1,225

Total current assets
 
12,534

 
11,577

Property, plant, and equipment, net of accumulated depreciation of $7,514 and $7,096
 
9,363

 
8,492

Goodwill
 
1,986

 
1,776

Other assets
 
1,688

 
1,832

Total assets
 
$
25,571

 
$
23,677

Liabilities and Shareholders’ Equity
Current liabilities:
 
 

 
 

Accounts payable
 
$
2,113

 
$
1,826

Accrued employee compensation and benefits
 
789

 
862

Other current liabilities
 
1,538

 
1,433

Total current liabilities
 
4,440

 
4,121

Long-term debt
 
4,820

 
4,820

Employee compensation and benefits
 
512

 
534

Other liabilities
 
1,238

 
986

Total liabilities
 
11,010

 
10,461

Shareholders’ equity:
 
 

 
 

Common shares, par value $2.50 per share - authorized 2,000 shares, issued 1,073 shares
 
2,683

 
2,683

Paid-in capital in excess of par value
 
424

 
455

Accumulated other comprehensive loss
 
(261
)
 
(273
)
Retained earnings
 
16,077

 
14,880

Treasury stock, at cost - 147 and 152 shares
 
(4,383
)
 
(4,547
)
Company shareholders’ equity
 
14,540

 
13,198

Noncontrolling interest in consolidated subsidiaries
 
21

 
18

Total shareholders’ equity
 
14,561

 
13,216

Total liabilities and shareholders’ equity
 
$
25,571

 
$
23,677

     See notes to condensed consolidated financial statements.
 
 
 
 


3


HALLIBURTON COMPANY
Condensed Consolidated Statements of Cash Flows
(Unaudited)

 
 
Six Months Ended
June 30
Millions of dollars
 
2012
 
2011
Cash flows from operating activities:
 
 
 
 
Net income
 
$
1,369

 
$
1,252

Adjustments to reconcile net income to net cash flows from operating activities:
 
 

 
 

Depreciation, depletion, and amortization
 
791

 
651

Loss contingency for Macondo well incident
 
300

 

Other changes:
 
 

 
 

Inventories
 
(724
)
 
(290
)
Receivables
 
(602
)
 
(583
)
Accounts payable
 
289

 
397

Other
 
(288
)
 
(39
)
Total cash flows from operating activities
 
1,135

 
1,388

Cash flows from investing activities:
 
 

 
 

Capital expenditures
 
(1,651
)
 
(1,423
)
Sales of marketable securities
 
200

 
701

Purchases of marketable securities
 
(100
)
 
(501
)
Other investing activities
 
34

 
(20
)
Total cash flows from investing activities
 
(1,517
)
 
(1,243
)
Cash flows from financing activities:
 
 

 
 

Dividends to shareholders
 
(167
)
 
(165
)
Other financing activities
 
25

 
80

Total cash flows from financing activities
 
(142
)
 
(85
)
Effect of exchange rate changes on cash
 
(2
)
 
(20
)
Increase (decrease) in cash and equivalents
 
(526
)
 
40

Cash and equivalents at beginning of period
 
2,698

 
1,398

Cash and equivalents at end of period
 
$
2,172

 
$
1,438

Supplemental disclosure of cash flow information:
 
 

 
 

Cash payments during the period for:
 
 

 
 

Interest
 
$
146

 
$
136

Income taxes
 
$
897

 
$
536

     See notes to condensed consolidated financial statements.
 
 
 
 


4


HALLIBURTON COMPANY
Notes to Condensed Consolidated Financial Statements
(Unaudited)

Note 1. Basis of Presentation
The accompanying unaudited condensed consolidated financial statements were prepared using generally accepted accounting principles for interim financial information and the instructions to Form 10-Q and Regulation S-X. Accordingly, these financial statements do not include all information or notes required by generally accepted accounting principles for annual financial statements and should be read together with our 2011 Annual Report on Form 10-K.
Our accounting policies are in accordance with United States generally accepted accounting principles. The preparation of financial statements in conformity with these accounting principles requires us to make estimates and assumptions that affect:
 
-
the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements; and
 
-
the reported amounts of revenue and expenses during the reporting period.
Ultimate results could differ from our estimates.
In our opinion, the condensed consolidated financial statements included herein contain all adjustments necessary to present fairly our financial position as of June 30, 2012, the results of our operations for the three and six months ended June 30, 2012 and 2011, and our cash flows for the six months ended June 30, 2012 and 2011. Such adjustments are of a normal recurring nature. In addition, certain reclassifications of prior period balances have been made to conform to 2012 classifications. The results of operations for the three and six months ended June 30, 2012 may not be indicative of results for the full year.

Note 2. Business Segment and Geographic Information
We operate under two divisions, which form the basis for the two operating segments we report: the Completion and Production segment and the Drilling and Evaluation segment.
The following table presents information on our business segments. “Corporate and other” includes expenses related to support functions and corporate executives. Also included are certain gains and losses not attributable to a particular business segment, such as the $300 million loss contingency related to the Macondo well incident recorded in “Corporate and other” during the first quarter of 2012.
Intersegment revenue was immaterial. Our equity in earnings and losses of unconsolidated affiliates that are accounted for by the equity method of accounting are included in revenue and operating income of the applicable segment.

 
 
Three Months Ended
June 30
 
Six Months Ended
June 30
Millions of dollars
 
2012
 
2011
 
2012
 
2011
Revenue:
 
 
 
 
 
 
 
 
Completion and Production
 
$
4,460

 
$
3,618

 
$
8,750

 
$
6,790

Drilling and Evaluation
 
2,774

 
2,317

 
5,352

 
4,427

Total revenue
 
$
7,234

 
$
5,935

 
$
14,102

 
$
11,217

Operating income:
 
 
 
 
 
 
 
 
Completion and Production
 
$
914

 
$
918

 
$
1,950

 
$
1,578

Drilling and Evaluation
 
393

 
324

 
761

 
554

Total operations
 
1,307

 
1,242

 
2,711

 
2,132

Corporate and other
 
(106
)
 
(81
)
 
(487
)
 
(157
)
Total operating income
 
$
1,201

 
$
1,161

 
$
2,224

 
$
1,975

Interest expense, net of interest income
 
(80
)
 
(63
)
 
(154
)
 
(132
)
Other, net
 
(17
)
 
(5
)
 
(24
)
 
(9
)
Income from continuing operations before income taxes
 
$
1,104

 
$
1,093

 
$
2,046

 
$
1,834


Receivables
As of June 30, 2012, 43% of our gross trade receivables were from customers in the United States. As of December 31, 2011, 45% of our gross trade receivables were from customers in the United States.


5


Note 3. Inventories
Inventories are stated at the lower of cost or market value. In the United States, we manufacture certain finished products and parts inventories for drill bits, completion products, bulk materials, and other tools that are recorded using the last-in, first-out method, which totaled $160 million as of both June 30, 2012 and December 31, 2011. If the average cost method had been used, total inventories would have been $42 million higher than reported as of June 30, 2012 and $36 million higher than reported as of December 31, 2011. The cost of the remaining inventory was recorded on the average cost method. Inventories consisted of the following:

Millions of dollars
 
June 30,
2012
 
December 31, 2011
Finished products and parts
 
$
2,405

 
$
1,801

Raw materials and supplies
 
773

 
673

Work in process
 
119

 
96

Total
 
$
3,297

 
$
2,570


Finished products and parts are reported net of obsolescence reserves of $110 million as of June 30, 2012 and $108 million as of December 31, 2011.

Note 4. Shareholders’ Equity
The following tables summarize our shareholders’ equity activity.
Millions of dollars
 
Total Shareholders' equity
 
Company shareholders' equity
 
Noncontrolling interest in consolidated subsidiaries
Balance at December 31, 2011
 
$
13,216

 
$
13,198

 
$
18

Transactions with shareholders
 
131

 
133

 
(2
)
Comprehensive income
 
1,381

 
1,376

 
5

Payments of dividends to shareholders
 
(167
)
 
(167
)
 

Balance at June 30, 2012
 
$
14,561

 
$
14,540

 
$
21

Millions of dollars
 
Total Shareholders' equity
 
Company shareholders' equity
 
Noncontrolling interest in consolidated subsidiaries
Balance at December 31, 2010
 
$
10,387

 
$
10,373

 
$
14

Transactions with shareholders
 
181

 
181

 

Comprehensive income
 
1,255

 
1,253

 
2

Payments of dividends to shareholders
 
(165
)
 
(165
)
 

Balance at June 30, 2011
 
$
11,658

 
$
11,642

 
$
16


The tax effects allocated to each component of other comprehensive income for the three and six months ended June 30, 2012 and 2011 are not material.

Accumulated other comprehensive loss consisted of the following:
Millions of dollars
 
June 30,
2012
 
December 31,
2011
Defined benefit and other postretirement liability adjustments
 
$
(194
)
 
$
(208
)
Cumulative translation adjustments
 
(67
)
 
(66
)
Unrealized gains on investments
 

 
1

Total accumulated other comprehensive loss
 
$
(261
)
 
$
(273
)

6


Note 5. KBR Separation
During 2007, we completed the separation of KBR, Inc. (KBR) from us by exchanging KBR common stock owned by us for our common stock. In addition, we recorded a liability reflecting the estimated fair value of the indemnities provided to KBR as described below. Since the separation, we have recorded adjustments to reflect changes to our estimation of our remaining obligation. All such adjustments are recorded in “Loss from discontinued operations, net of income tax benefit.”
We entered into various agreements relating to the separation of KBR, including, among others, a master separation agreement and a tax sharing agreement. We agreed to provide indemnification in favor of KBR under the master separation agreement for all out-of-pocket cash costs and expenses, or cash settlements or cash arbitration awards in lieu thereof, KBR may incur after the effective date of the master separation agreement as a result of the replacement of the subsea flowline bolts installed in connection with the Barracuda-Caratinga project.
The tax sharing agreement provides for the calculation and allocation of United States and certain other jurisdiction tax liabilities between us and KBR for the periods 2001 through the date of separation. The tax sharing agreement is complex, and finalization of amounts owed between KBR and us under the tax sharing agreement can occur only after income tax audits are completed by the taxing authorities and both parties have had time to analyze the results.
During the second quarter of 2012, we sent a notice as required by the tax sharing agreement to KBR requesting the appointment of an arbitrator in accordance with the terms of the tax sharing agreement. This request asked the arbitrator to find that KBR owes us $256 million pursuant to the tax sharing agreement. KBR denied that it owes us any amount and asserted instead that we owe KBR certain amounts under the tax sharing agreement. KBR also asserted that they believe the master separation agreement controls this matter and demanded arbitration under that agreement. On July 10, 2012, we filed suit in the District Court of Harris County, Texas, seeking to compel KBR to arbitrate this dispute in accordance with the provisions of the tax sharing agreement, rather than the master separation agreement. No anticipated recovery amounts related to this matter have been recognized in the condensed consolidated financial statements.
Amounts accrued relating to our remaining KBR liabilities are primarily included in “Other liabilities” on the condensed consolidated balance sheets and totaled $215 million as of June 30, 2012 and $201 million as of December 31, 2011. See Note 6 for further discussion of the Barracuda-Caratinga matter.

Note 6. Commitments and Contingencies
Macondo well incident
Overview. The semisubmersible drilling rig, Deepwater Horizon, sank on April 22, 2010 after an explosion and fire onboard the rig that began on April 20, 2010. The Deepwater Horizon was owned by Transocean Ltd. and had been drilling the Macondo exploration well in Mississippi Canyon Block 252 in the Gulf of Mexico for the lease operator, BP Exploration & Production, Inc. (BP Exploration), an indirect wholly owned subsidiary of BP p.l.c. We performed a variety of services for BP Exploration, including cementing, mud logging, directional drilling, measurement-while-drilling, and rig data acquisition services. Crude oil flowing from the well site spread across thousands of square miles of the Gulf of Mexico and reached the United States Gulf Coast. Numerous attempts at estimating the volume of oil spilled have been made by various groups, and on August 2, 2010 the federal government published an estimate that approximately 4.9 million barrels of oil were discharged from the well. Efforts to contain the flow of hydrocarbons from the well were led by the United States government and by BP p.l.c., BP Exploration, and their affiliates (collectively, BP). The flow of hydrocarbons from the well ceased on July 15, 2010, and the well was permanently capped on September 19, 2010. There were eleven fatalities and a number of injuries as a result of the Macondo well incident.
We are currently unable to fully estimate the impact the Macondo well incident will have on us. The beginning of the multi-district litigation (MDL) trial referred to below has been delayed to January 2013 in connection with the pending settlement between BP and the Plaintiffs’ Steering Committee (PSC) in the MDL. In addition, BP has settled litigation with several defendants in the MDL. We cannot predict the outcome of the many lawsuits and investigations relating to the Macondo well incident, including orders and rulings of the court that impact the MDL, whether the MDL will proceed to trial, the results of any such trial, the final settlement arrangement between BP and the PSC, the effect that settlement may have on claims against us, or whether we might settle with one or more of the parties to any lawsuit or investigation. At the request of the court, in late February 2012 we participated in a series of discussions with the Magistrate Judge in the MDL relating to whether the MDL could be settled. Although these discussions did not result in a settlement, we recorded a $300 million liability during the first quarter of 2012 for an estimated loss contingency relating to the MDL. This loss contingency, which is included in “Other liabilities” on the condensed consolidated balance sheet as of June 30, 2012 and in “Cost of services” on the condensed consolidated statement of operations for the six months ended June 30, 2012, represents a loss contingency that is probable and for which a reasonable estimate of a loss or range of loss can be made. Although we continue to believe that we have substantial legal arguments and defenses against any liability and that BP's indemnity obligation protects us, we cannot conclude that a probable loss associated with the MDL is zero. There are additional loss contingencies relating to the Macondo well incident that are reasonably possible but for which we cannot make a reasonable estimate. Given the numerous potential developments relating to the MDL and other lawsuits and investigations, which could occur at any time, we may adjust our estimated loss contingency in the future. Liabilities arising out of the Macondo well incident could have a material adverse effect on our liquidity, consolidated results of operations, and consolidated financial condition.

7


Investigations and Regulatory Action. The United States Coast Guard, a component of the United States Department of Homeland Security, and the Bureau of Ocean Energy Management, Regulation and Enforcement (BOEMRE) (formerly known as the Minerals Management Service (MMS) and which was replaced effective October 1, 2011 by two new, independent bureaus – the Bureau of Safety and Environmental Enforcement (BSEE) and the Bureau of Ocean Energy Management (BOEM)), a bureau of the United States Department of the Interior, shared jurisdiction over the investigation into the Macondo well incident and formed a joint investigation team that reviewed information and held hearings regarding the incident (Marine Board Investigation). We were named as one of the 16 parties-in-interest in the Marine Board Investigation. The Marine Board Investigation, as well as investigations of the incident that were conducted by The National Commission on the BP Deepwater Horizon Oil Spill and Offshore Drilling (National Commission) and the National Academy of Sciences, have been completed, and reports issued as a result of those investigations are discussed below. In addition, the Chemical Safety Board is conducting an investigation to examine the root causes of the accidental release of hydrocarbons from the Macondo well, including an examination of key technical factors, the safety cultures involved, and the effectiveness of relevant laws, regulations, and industry standards.
DOJ Investigations and Actions. On June 1, 2010, the United States Attorney General announced that the Department of Justice (DOJ) was launching civil and criminal investigations into the Macondo well incident to closely examine the actions of those involved, and that the DOJ was working with attorneys general of states affected by the Macondo well incident. The DOJ announced that it was reviewing, among other traditional criminal statutes, possible violations of and liabilities under The Clean Water Act (CWA), The Oil Pollution Act of 1990 (OPA), The Migratory Bird Treaty Act of 1918 (MBTA), and the Endangered Species Act of 1973 (ESA). As part of its criminal investigation, the DOJ is examining certain aspects of our conduct after the incident, including with respect to record-keeping, record retention, post-incident testing and modeling, securities filings, and public statements by us or our employees, to evaluate whether there has been any violation of federal law.
The CWA provides authority for civil and criminal penalties for discharges of oil into or upon navigable waters of the United States, adjoining shorelines, or in connection with the Outer Continental Shelf Lands Act (OCSLA) in quantities that are deemed harmful. A single discharge event may result in the assertion of numerous violations under the CWA. Criminal sanctions under the CWA can be assessed for negligent discharges (up to $50,000 per day per violation), for knowing discharges (up to $100,000 per day per violation), and for knowing endangerment (up to $2 million per violation), and federal agencies could be precluded from contracting with a company that is criminally sanctioned under the CWA. Civil proceedings under the CWA can be commenced against an “owner, operator, or person in charge of any vessel, onshore facility, or offshore facility from which oil or a hazardous substance is discharged” in violation of the CWA. The civil penalties that can be imposed against responsible parties range from up to $1,100 per barrel of oil discharged in the case of those found strictly liable to $4,300 per barrel of oil discharged in the case of those found to have been grossly negligent.
The OPA establishes liability for discharges of oil from vessels, onshore facilities, and offshore facilities into or upon the navigable waters of the United States. Under the OPA, the “responsible party” for the discharging vessel or facility is liable for removal and response costs as well as for damages, including recovery costs to contain and remove discharged oil and damages for injury to natural resources and real or personal property, lost revenues, lost profits, and lost earning capacity. The cap on liability under the OPA is the full cost of removal of the discharged oil plus up to $75 million for damages, except that the $75 million cap does not apply in the event the damage was proximately caused by gross negligence or the violation of certain federal safety, construction or operating standards. The OPA defines the set of responsible parties differently depending on whether the source of the discharge is a vessel or an offshore facility. Liability for vessels is imposed on owners and operators; liability for offshore facilities is imposed on the holder of the permit or lessee of the area in which the facility is located.
The MBTA and the ESA provide penalties for injury and death to wildlife and bird species. The MBTA provides that violators are strictly liable and such violations are misdemeanor crimes subject to fines of up to $15,000 per bird killed and imprisonment of up to six months. The ESA provides for civil penalties for knowing violations that can range up to $25,000 per violation and, in the case of criminal penalties, up to $50,000 per violation.
In addition, federal law provides for a variety of fines and penalties, the most significant of which is the Alternative Fines Act. In lieu of the express amount of the criminal fines that may be imposed under some of the statutes described above, the Alternative Fines Act provides for a fine in the amount of twice the gross economic loss suffered by third parties, which amount, although difficult to estimate, is significant.

8


On December 15, 2010, the DOJ filed a civil action seeking damages and injunctive relief against BP Exploration, Anadarko Petroleum Corporation and Anadarko E&P Company LP (together, Anadarko), which had an approximate 25% interest in the Macondo well, certain subsidiaries of Transocean Ltd., and others for violations of the CWA and the OPA. The DOJ’s complaint seeks an action declaring that the defendants are strictly liable under the CWA as a result of harmful discharges of oil into the Gulf of Mexico and upon United States shorelines as a result of the Macondo well incident. The complaint also seeks an action declaring that the defendants are strictly liable under the OPA for the discharge of oil that has resulted in, among other things, injury to, loss of, loss of use of, or destruction of natural resources and resource services in and around the Gulf of Mexico and the adjoining United States shorelines and resulting in removal costs and damages to the United States far exceeding $75 million. BP Exploration has been designated, and has accepted the designation, as a responsible party for the pollution under the CWA and the OPA. Others have also been named as responsible parties, and all responsible parties may be held jointly and severally liable for any damages under the OPA. A responsible party may make a claim for contribution against any other responsible party or against third parties it alleges contributed to or caused the oil spill. In connection with the proceedings discussed below under “Litigation,” in April 2011 BP Exploration filed a claim against us for contribution with respect to liabilities incurred by BP Exploration under the OPA or another law and requested a judgment that the DOJ assert its claims for OPA financial liability directly against us. We filed a motion to dismiss BP Exploration’s claim, and that motion is pending.
We have not been named as a responsible party under the CWA or the OPA in the DOJ civil action, and we do not believe we are a responsible party under the CWA or the OPA. While we are not included in the DOJ’s civil complaint, there can be no assurance that the DOJ or other federal or state governmental authorities will not bring an action, whether civil or criminal, against us under the CWA, the OPA, and/or other statutes or regulations. In connection with the DOJ’s filing of the civil action, it announced that its criminal and civil investigations are continuing and that it will employ efforts to hold accountable those who are responsible for the incident.
A federal grand jury has been convened in Louisiana to investigate potential criminal conduct in connection with the Macondo well incident. We are cooperating fully with the DOJ’s criminal investigation. As of July 27, 2012, the DOJ has not commenced any criminal proceedings against us. We cannot predict the status or outcome of the DOJ’s criminal investigation or estimate the potential impact the investigation may have on us or our liability assessment, all of which may change as the investigation progresses.We have had and expect to continue to have discussions with the DOJ regarding the Macondo well incident and associated pre-incident and post-incident conduct.
Investigative Reports. On September 8, 2010, an incident investigation team assembled by BP issued the Deepwater Horizon Accident Investigation Report (BP Report). The BP Report outlined eight key findings of BP related to the possible causes of the Macondo well incident, including failures of cement barriers, failures of equipment provided by other service companies and the drilling contractor, and failures of judgment by BP and the drilling contractor. With respect to the BP Report’s assessment that the cement barrier did not prevent hydrocarbons from entering the wellbore after cement placement, the BP Report concluded that, among other things, there were “weaknesses in cement design and testing.” According to the BP Report, the BP incident investigation team did not review its analyses or conclusions with us or any other entity or governmental agency conducting a separate or independent investigation of the incident. In addition, the BP incident investigation team did not conduct any testing using our cementing products.
On June 22, 2011, Transocean released its internal investigation report on the causes of the Macondo well incident. Transocean’s report, among other things, alleges deficiencies with our cementing services on the Deepwater Horizon. Like the BP Report, the Transocean incident investigation team did not review its analyses or conclusions with us and did not conduct any testing using our cementing products.
On January 11, 2011, the National Commission released “Deep Water -- The Gulf Oil Disaster and the Future of Offshore Drilling,” its investigation report (Investigation Report) to the President of the United States regarding, among other things, the National Commission’s conclusions of the causes of the Macondo well incident. According to the Investigation Report, the “immediate causes” of the incident were the result of a series of missteps, oversights, miscommunications and failures to appreciate risk by BP, Transocean, and us, although the National Commission acknowledged that there were still many things it did not know about the incident, such as the role of the blowout preventer. The National Commission also acknowledged that it may never know the extent to which each mistake or oversight caused the Macondo well incident, but concluded that the immediate cause was “a failure to contain hydrocarbon pressures in the well,” and pointed to three things that could have contained those pressures: “the cement at the bottom of the well, the mud in the well and in the riser, and the blowout preventer.” In addition, the Investigation Report stated that “primary cement failure was a direct cause of the blowout” and that cement testing performed by an independent laboratory “strongly suggests” that the foam cement slurry used on the Macondo well was unstable. The Investigation Report, however, acknowledges a fact widely accepted by the industry that cementing wells is a complex endeavor utilizing an inherently uncertain process in which failures are not uncommon and that, as a result, the industry utilizes the negative-pressure test and cement bond log test, among others, to identify cementing failures that require remediation before further work on a well is performed.

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The Investigation Report also sets forth the National Commission’s findings on certain missteps, oversights and other factors that may have caused, or contributed to the cause of, the incident, including BP’s decision to use a long string casing instead of a liner casing, BP’s decision to use only six centralizers, BP’s failure to run a cement bond log, BP’s reliance on the primary cement job as a barrier to a possible blowout, BP’s and Transocean’s failure to properly conduct and interpret a negative-pressure test, BP’s temporary abandonment procedures, and the failure of the drilling crew and our surface data logging specialist to recognize that an unplanned influx of oil, gas, or fluid into the well (known as a “kick”) was occurring. With respect to the National Commission’s finding that our surface data logging specialist failed to recognize a kick, the Investigation Report acknowledged that there were simultaneous activities and other monitoring responsibilities that may have prevented the surface data logging specialist from recognizing a kick.
The Investigation Report also identified two general root causes of the Macondo well incident: systemic failures by industry management, which the National Commission labeled “the most significant failure at Macondo,” and failures in governmental and regulatory oversight. The National Commission cited examples of failures by industry management such as BP’s lack of controls to adequately identify or address risks arising from changes to well design and procedures, the failure of BP’s and our processes for cement testing, communication failures among BP, Transocean, and us, including with respect to the difficulty of our cement job, Transocean’s failure to adequately communicate lessons from a recent near-blowout, and the lack of processes to adequately assess the risk of decisions in relation to the time and cost those decisions would save. With respect to failures of governmental and regulatory oversight, the National Commission concluded that applicable drilling regulations were inadequate, in part because of a lack of resources and political support of the MMS, and a lack of expertise and training of MMS personnel to enforce regulations that were in effect.
As a result of the factual and technical complexity of the Macondo well incident, the Chief Counsel of the National Commission issued a separate, more detailed report regarding the technical, managerial, and regulatory causes of the Macondo well incident in February 2011.
In March 2011, a third party retained by the BOEMRE to undertake a forensic examination and evaluation of the blowout preventer stack, its components and associated equipment, released a report detailing its findings. The forensic examination report found, among other things, that the blowout preventer stack failed primarily because the blind sheer rams did not fully close and seal the well due to a portion of drill pipe that had become trapped between the blocks and the pipe being outside the cutting surface of the ram blades. The forensic examination report recommended further examination, investigation, and testing, which found that the redundant operating pods of the blowout preventer may not have timely activated the blind shear rams in the automatic mode function due to a depleted battery in one pod and a miswired solenoid in the other pod. We had no part in manufacturing or servicing the blowout preventer stack.
In September 2011, the BOEMRE released the final report of the Marine Board Investigation regarding the Macondo well incident (BOEMRE Report). A panel of investigators of the BOEMRE identified a number of causes of the Macondo well incident. According to the BOEMRE Report, “a central cause of the blowout was failure of a cement barrier in the production casing string.” The panel was unable to identify the precise reasons for the failure but concluded that it was likely due to: “(1) swapping of cement and drilling mud in the shoe track (the section of casing near the bottom of the well); (2) contamination of the shoe track cement; or (3) pumping the cement past the target location in the well, leaving the shoe track with little or no cement.” Generally, the panel concluded that the Macondo well incident was the result of, among other things, poor risk management, last-minute changes to drilling plans, failure to observe and respond to critical indicators, and inadequate well control response by the companies and individuals involved. In particular, the BOEMRE Report stated that BP made a series of decisions that complicated the cement job and may have contributed to the failure of the cement job, including the use of only one cement barrier, the location of the production casing, and the failure to follow industry-accepted recommendations.
The BOEMRE Report also stated, among other things, that BP failed to properly communicate well design and cementing decisions and risks to Transocean, that BP and Transocean failed to correctly interpret the negative-pressure test, and that we, BP, and Transocean failed to detect the influx of hydrocarbons into the well. According to the BOEMRE Report, the panel found evidence that we, among others, violated federal regulations relating to the failure to take measures to prevent the unauthorized release of hydrocarbons, the failure to take precautions to keep the well under control, and the failure to cement the well in a manner that would, among other things, prevent the release of fluids into the Gulf of Mexico. In October 2011, the BSEE issued a notification of Incidents of Noncompliance (INCs) to us for violating those regulations and a federal regulation relating to the failure to protect health, safety, property, and the environment as a result of a failure to perform operations in a safe and workmanlike manner. According to the BSEE’s notice, we did not ensure an adequate barrier to hydrocarbon flow after cementing the production casing and did not detect the influx of hydrocarbons until they were above the blowout preventer stack. We understand that the regulations in effect at the time of the alleged violations provide for fines of up to $35,000 per day per violation. We have appealed the INCs to the Interior Board of Land Appeals (IBLA). In January 2012, the IBLA, in response to our and the BSEE’s joint request, has suspended the appeal and has ordered us and the BSEE to file notice within 15 days after the conclusion of the MDL and, within 60 days after the MDL court issues a final decision, to file a proposal for further action in the appeal. The BSEE has announced that the INCs will be reviewed for possible imposition of civil penalties once the appeal has ended. The BSEE has stated that this is the first time the Department of the Interior has issued INCs directly to a contractor that was not the well’s operator.

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In December 2011, the National Academy of Sciences released a pre-publication copy of its report examining the causes of the Macondo well incident and identifying measures for preventing similar incidents in the future (NAS Report). The NAS Report noted that it does not attempt to assign responsibility to specific individuals or entities or determine the extent that the parties involved complied with applicable regulations.
According to the NAS Report, the flow of hydrocarbons that led to the blowout began when drilling mud was displaced by seawater during the temporary abandonment process, which was commenced by the drilling team despite a failure to demonstrate the integrity of the cement job after multiple negative pressure tests and after incorrectly deciding that a negative pressure test indicated that the cement barriers were effective. In addition, the NAS Report found, among other things, that: the approach chosen for well completion failed to provide adequate safety margins considering the reservoir formation; the loss of well control was not noted until more than 50 minutes after hydrocarbon flow from the formation had started; the blowout preventer was not designed or tested for the dynamic conditions that most likely existed at the time attempts were made to recapture well control; and the entities involved did not provide an effective systems safety approach commensurate with the risks of the Macondo well. According to the NAS Report, a number of key decisions related to the design, construction, and testing of the barriers critical to the temporary abandonment process were flawed.
The NAS Report also found, among other things, that the heavier “tail” cement slurry, intended for placement in the Macondo well shoe track, was “gravitationally unstable” on top of the lighter foam cement slurry and that the heavier tail cement slurry probably fell into or perhaps through the lighter foam cement slurry during pumping into the well, which would have left a tail slurry containing foam cement in the shoe track. The NAS Report also found, among other things, that foam cement that may have been inadvertently left in the shoe track likely would not have had the strength to resist crushing when experiencing the differential pressures exerted on the cement during the negative pressure test. In addition, the NAS Report found, among other things, that evidence available before the blowout indicated that the flapper valves in the float collar probably failed to seal, but the evidence was not acted upon and, due to BP’s choice of a long-string production casing and the lack of minimum circulation of the well prior to the cement job, the possibility of mud-filled channels or poor cement bonding existed.
The NAS Report also set forth the following observations, among others: (1) there were alternative completion techniques and operational processes available that could have safely prepared the well for temporary abandonment; (2) post-incident static tests on a foam cement slurry similar to the slurry pumped into the Macondo well were performed under laboratory conditions and exhibited the settling of cement and nitrogen breakout, although because the tests were not conducted at bottom hole conditions “it is impossible to say whether the foam was stable at the bottom of the well”; (3) the “cap” cement slurry was subject to contamination by the spacer or the drilling mud that was placed ahead of the cap cement slurry and, if the cap cement slurry was heavily contaminated, it would not reach the strength of uncontaminated cement; (4) the numerous companies involved and the division of technical expertise among those companies affected their ability to perform and maintain an integrated assessment of the margins of safety for the Macondo well; (5) the regulatory regime was ineffective in addressing the risks of the Macondo well; and (6) training of key personnel and decision makers in the industry and regulatory agencies has been inadequate relative to the risks and complexities of deepwater drilling.
The NAS Report recommended, among other things: that all primary cemented barriers to flow should be tested to verify quality, quantity, and location of cement; that the integrity of mechanical barriers should be verified by using the best available test procedures; that blowout preventer systems should be redesigned for the drilling environment to which they are being applied; and that operating companies should have ultimate responsibility and accountability for well integrity, well design, well construction, and the suitability of the rig and associated safety equipment.
The Cementing Job and Reaction to Reports. We disagree with the BP Report, the National Commission, Transocean’s report, the BOEMRE Report, and the NAS Report regarding many of their findings and characterizations with respect to the cementing and surface data logging services, as applicable, on the Deepwater Horizon. We have provided information to the National Commission, its staff, and representatives of the joint investigation team for the Marine Board Investigation that we believe has been overlooked or selectively omitted from the Investigation Report and the BOEMRE Report, as applicable. We intend to continue to vigorously defend ourselves in any investigation relating to our involvement with the Macondo well that we believe inaccurately evaluates or depicts our services on the Deepwater Horizon.
The cement slurry on the Deepwater Horizon was designed and prepared pursuant to well condition data provided by BP. Regardless of whether alleged weaknesses in cement design and testing are or are not ultimately established, and regardless of whether the cement slurry was utilized in similar applications or was prepared consistent with industry standards, we believe that had BP and Transocean properly interpreted a negative-pressure test, this test would have revealed any problems with the cement. In addition, had BP designed the Macondo well to allow a full cement bond log test or if BP had conducted even a partial cement bond log test, the test likely would have revealed any problems with the cement. BP, however, elected not to conduct any cement bond log tests, and with Transocean misinterpreted the negative-pressure test, both of which could have resulted in remedial action, if appropriate, with respect to the cementing services.
At this time we cannot predict the impact of the Investigation Report, the BOEMRE Report, the NAS Report, or the conclusions of future reports of the Chemical Safety Board or others. We also cannot predict whether their investigations or any other report or investigation will have an influence on or result in us being named as a party in any action alleging liability or violation of a statute or regulation, whether federal or state and whether criminal or civil.

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We intend to continue to cooperate fully with all hearings, investigations, and requests for information relating to the Macondo well incident. We cannot predict the outcome of, or the costs to be incurred in connection with, any of these hearings or investigations, and therefore we cannot predict the potential impact they may have on us.
Litigation. Since April 21, 2010, plaintiffs have been filing lawsuits relating to the Macondo well incident. Generally, those lawsuits allege either (1) damages arising from the oil spill pollution and contamination (e.g., diminution of property value, lost tax revenue, lost business revenue, lost tourist dollars, inability to engage in recreational or commercial activities) or (2) wrongful death or personal injuries. We are named along with other unaffiliated defendants in more than 400 complaints, most of which are alleged class actions, involving pollution damage claims and at least seven personal injury lawsuits involving four decedents and at least 11 allegedly injured persons who were on the drilling rig at the time of the incident. At least six additional lawsuits naming us and others relate to alleged personal injuries sustained by those responding to the explosion and oil spill. Plaintiffs originally filed the lawsuits described above in federal and state courts throughout the United States. Except for certain lawsuits not yet consolidated, the Judicial Panel on Multi-District Litigation ordered all of the lawsuits against us consolidated in the MDL proceeding before Judge Carl Barbier in the United States Eastern District of Louisiana. The pollution complaints generally allege, among other things, negligence and gross negligence, property damages, taking of protected species, and potential economic losses as a result of environmental pollution and generally seek awards of unspecified economic, compensatory, and punitive damages, as well as injunctive relief. Plaintiffs in these pollution cases have brought suit under various legal provisions, including the OPA, the CWA, the MBTA, the ESA, the OCSLA, the Longshoremen and Harbor Workers Compensation Act, general maritime law, state common law, and various state environmental and products liability statutes.
Furthermore, the pollution complaints include suits brought against us by governmental entities, including the State of Alabama, the State of Louisiana, Plaquemines Parish, the City of Greenville, and three Mexican states. Complaints brought against us by at least seven other parishes in Louisiana were dismissed with prejudice, and the dismissal is being appealed by those parishes. The wrongful death and other personal injury complaints generally allege negligence and gross negligence and seek awards of compensatory damages, including unspecified economic damages and punitive damages. We have retained counsel and are investigating and evaluating the claims, the theories of recovery, damages asserted, and our respective defenses to all of these claims.
Judge Barbier is also presiding over a separate proceeding filed by Transocean under the Limitation of Liability Act (Limitation Action). In the Limitation Action, Transocean seeks to limit its liability for claims arising out of the Macondo well incident to the value of the rig and its freight. Although the Limitation Action is not consolidated in the MDL, to this point the judge is effectively treating the two proceedings as associated cases. In February 2011, Transocean tendered us, along with all other defendants, into the Limitation Action. As a result of the tender, we and all other defendants will be treated as direct defendants to the plaintiffs’ claims as if the plaintiffs had sued each of us and the other defendants directly. In the Limitation Action, the judge intends to determine the allocation of liability among all defendants in the hundreds of lawsuits associated with the Macondo well incident, including those in the MDL proceeding that are pending in his court. Specifically, the judge will determine the liability, limitation, exoneration, and fault allocation with regard to all of the defendants in a trial, which is scheduled to occur in at least two phases beginning in January 2013. The initial two phases of this portion of the trial are scheduled to cover issues arising out of the conduct of various parties allegedly relevant to the loss of well control, the ensuing fire and explosion on and sinking of the Deepwater Horizon, the initiation of the release of hydrocarbons from the Macondo well, the actions relating to the attempts to control the flow of hydrocarbons from the well, and the quantification of hydrocarbons discharged from the well. Subsequent proceedings would be held to the extent triable issues remain unsolved by the first two phases of the trial, settlements, motion practice, or stipulation. We do not believe that a single apportionment of liability in the Limitation Action is properly applied, particularly with respect to gross negligence and punitive damages, to the hundreds of lawsuits pending in the MDL proceeding.
Damages for the cases tried in the MDL proceeding, including punitive damages, are expected to be tried following the portion of the trial described above. Under ordinary MDL procedures, such cases would, unless waived by the respective parties, be tried in the courts from which they were transferred into the MDL. It remains unclear, however, what impact the overlay of the Limitation Action will have on where these matters are tried. Document discovery and depositions among the parties to the MDL are ongoing. It is unclear how the judge will address the DOJ’s civil action for alleged violations of the CWA and the OPA.

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In April and May 2011, certain defendants in the proceedings described above filed numerous cross claims and third party claims against certain other defendants. BP Exploration and BP America Production Company filed claims against us seeking subrogation and contribution, including with respect to liabilities under the OPA, and direct damages, and alleging negligence, gross negligence, fraudulent conduct, and fraudulent concealment. Transocean filed claims against us seeking indemnification, and subrogation and contribution, including with respect to liabilities under the OPA and for the total loss of the Deepwater Horizon, and alleging comparative fault and breach of warranty of workmanlike performance. Anadarko filed claims against us seeking tort indemnity and contribution, and alleging negligence, gross negligence and willful misconduct, and MOEX Offshore 2007 LLC (MOEX), who has an approximate 10% interest in the Macondo well, filed a claim against us alleging negligence. Cameron International Corporation (Cameron) (the manufacturer and designer of the blowout preventer), M-I Swaco (provider of drilling fluids and services, among other things), Weatherford U.S. L.P. and Weatherford International, Inc. (together, Weatherford) (providers of casing components, including float equipment and centralizers, and services), and Dril-Quip, Inc. (Dril-Quip) (provider of wellhead systems), each filed claims against us seeking indemnification and contribution, including with respect to liabilities under the OPA in the case of Cameron, and alleging negligence. Additional civil lawsuits may be filed against us. In addition to the claims against us, generally the defendants in the proceedings described above filed claims, including for liabilities under the OPA and other claims similar to those described above, against the other defendants described above. BP has since announced that it has settled those claims between it and each of MOEX, Weatherford, Anadarko, and Cameron. We also understand that BP and M-I Swaco have agreed to dismiss all claims between them.
In April 2011, we filed claims against BP Exploration, BP p.l.c. and BP America Production Company (BP Defendants), M-I Swaco, Cameron, Anadarko, MOEX, Weatherford, Dril-Quip, and numerous entities involved in the post-blowout remediation and response efforts, in each case seeking contribution and indemnification and alleging negligence. Our claims also alleged gross negligence and willful misconduct on the part of the BP Defendants, Anadarko, and Weatherford. We also filed claims against M-I Swaco and Weatherford for contractual indemnification, and against Cameron, Weatherford and Dril-Quip for strict products liability, although the court has since issued orders dismissing all claims asserted against Dril-Quip and Weatherford in the MDL and we have dismissed our contractual indemnification claim against M-I Swaco. We filed our answer to Transocean’s Limitation petition denying Transocean’s right to limit its liability, denying all claims and responsibility for the incident, seeking contribution and indemnification, and alleging negligence and gross negligence.
Judge Barbier has issued an order, among others, clarifying certain aspects of law applicable to the lawsuits pending in his court. The court ruled that: (1) general maritime law will apply and therefore dismissed all claims brought under state law causes of action; (2) general maritime law claims may be brought directly against defendants who are non-“responsible parties” under the OPA with the exception of pure economic loss claims by plaintiffs other than commercial fishermen; (3) all claims for damages, including pure economic loss claims, may be brought under the OPA directly against responsible parties; and (4) punitive damage claims can be brought against both responsible and non-responsible parties under general maritime law. As discussed above, with respect to the ruling that claims for damages may be brought under the OPA against responsible parties, we have not been named as a responsible party under the OPA, but BP Exploration has filed a claim against us for contribution with respect to liabilities incurred by BP Exploration under the OPA.
In September 2011, we filed claims in Harris County, Texas against the BP Defendants seeking damages, including lost profits and exemplary damages, and alleging negligence, grossly negligent misrepresentation, defamation, common law libel, slander, and business disparagement. Our claims allege that the BP Defendants knew or should have known about an additional hydrocarbon zone in the well that the BP Defendants failed to disclose to us prior to our designing the cement program for the Macondo well. The location of the hydrocarbon zones is critical information required prior to performing cementing services and is necessary to achieve desired cement placement. We believe that had the BP Defendants disclosed the hydrocarbon zone to us, we would not have proceeded with the cement program unless it was redesigned, which likely would have required a redesign of the production casing. In addition, we believe that the BP Defendants withheld this information from the BP Report and from the various investigations discussed above. In connection with the foregoing, we also moved to amend our claims against the BP Defendants in the MDL proceeding to include fraud. The BP Defendants have denied all of the allegations relating to the additional hydrocarbon zone and filed a motion to prevent us from adding our fraud claim in the MDL. In October 2011, our motion to add the fraud claim against the BP Defendants in the MDL proceeding was denied. The court’s ruling does not, however, prevent us from using the underlying evidence in our pending claims against the BP Defendants.
In December 2011, BP filed a motion for sanctions against us alleging, among other things, that we destroyed evidence relating to post-incident testing of the foam cement slurry on the Deepwater Horizon and requesting adverse findings against us. A magistrate judge in the MDL proceeding denied BP’s motion. BP appealed that ruling, and Judge Barbier affirmed the magistrate judge’s decision.

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In April 2012, BP announced that it had reached definitive settlement agreements with the PSC to resolve the substantial majority of eligible private economic loss and medical claims stemming from the Macondo well incident. The PSC acts on behalf of individuals and business plaintiffs in the MDL. BP has estimated that the cost of the pending settlement would be approximately $7.8 billion, including administration costs and plaintiffs’ attorneys’ fees and expenses, and stated that it is possible the actual cost could be higher or lower. According to BP, the proposed settlement does not include claims against BP made by the DOJ or other federal agencies or by states and local governments. In addition, BP has stated that the proposed settlement provides that, to the extent permitted by law, BP will assign to the PSC certain of its claims, rights and recoveries against Transocean and us for damages not recoverable from BP. We do not believe that our contract with BP Exploration permits the assignment of certain claims to the PSC without our consent. In April and May, 2012, BP and the PSC filed two settlement agreements and amendments with the MDL court, one agreement addressing economic claims and one agreement addressing medical claims, as well as numerous supporting documents and motions requesting that the court approve, among other things, the certification of the classes for both settlements and a schedule for holding a fairness hearing and approving the settlements. In May 2012, the MDL court preliminarily and conditionally certified the classes for both settlements and preliminarily approved the proposed settlements. The MDL court has ordered that any objections to the settlements be filed by the end of August 2012, with hearings on the certification of the classes and fairness of the settlements to begin in November 2012 and with the initial phase of the MDL trial to commence in January 2013. We intend to object to the settlement and take other appropriate actions to protect our interests. We are unable to predict at this time the effect that the settlements may have on claims against us.
We intend to vigorously defend any litigation, fines, and/or penalties relating to the Macondo well incident and to vigorously pursue any damages, remedies, or other rights available to us as a result of the Macondo well incident. We have incurred and expect to continue to incur significant legal fees and costs, some of which we expect to be covered by indemnity or insurance, as a result of the numerous investigations and lawsuits relating to the incident.
Macondo derivative case. In February 2011, a shareholder who had previously made a demand on our Board of Directors with respect to another derivative lawsuit filed a shareholder derivative lawsuit relating to the Macondo well incident. See “Shareholder derivative cases” below.
Indemnification and Insurance. Our contract with BP Exploration relating to the Macondo well generally provides for our indemnification by BP Exploration for certain potential claims and expenses relating to the Macondo well incident, including those resulting from pollution or contamination (other than claims by our employees, loss or damage to our property, and any pollution emanating directly from our equipment). Also, under our contract with BP Exploration, we have, among other things, generally agreed to indemnify BP Exploration and other contractors performing work on the well for claims for personal injury of our employees and subcontractors, as well as for damage to our property. In turn, we believe that BP Exploration was obligated to obtain agreement by other contractors performing work on the well to indemnify us for claims for personal injury of their employees or subcontractors, as well as for damages to their property. We have entered into separate indemnity agreements with Transocean and M-I Swaco, under which we have agreed to indemnify those parties for claims for personal injury of our employees and subcontractors and they have agreed to indemnify us for claims for personal injury of their employees and subcontractors.
In April 2011, we filed a lawsuit against BP Exploration in Harris County, Texas to enforce BP Exploration’s contractual indemnity and alleging BP Exploration breached certain terms of the contractual indemnity provision. BP Exploration removed that lawsuit to federal court in the Southern District of Texas, Houston Division. We filed a motion to remand the case to Harris County, Texas, and the lawsuit was transferred to the MDL.
BP Exploration, in connection with filing its claims with respect to the MDL proceeding, asked that court to declare that it is not liable to us in contribution, indemnification, or otherwise with respect to liabilities arising from the Macondo well incident. Other defendants in the litigation discussed above have generally denied any obligation to contribute to any liabilities arising from the Macondo well incident.
In January 2012, the court in the MDL proceeding entered an order in response to our and BP’s motions for summary judgment regarding certain indemnification matters. The court held that BP is required to indemnify us for third-party compensatory claims, or actual damages, that arise from pollution or contamination that did not originate from our property or equipment located above the surface of the land or water, even if we are found to be grossly negligent. The court did not express an opinion as to whether our conduct amounted to gross negligence, but we do not believe the performance of our services on the Deepwater Horizon constituted gross negligence. The court also held, however, that BP does not owe us indemnity for punitive damages or for civil penalties under the CWA, if any, and that fraud could void the indemnity on public policy grounds, although the court stated that it was mindful that mere failure to perform contractual obligations as promised does not constitute fraud. As discussed above, the DOJ is not seeking civil penalties from us under the CWA. The court in the MDL proceeding deferred ruling on whether our indemnification from BP covers penalties or fines under the OCSLA, whether our alleged breach of our contract with BP Exploration would invalidate the indemnity, and whether we committed an act that materially increased the risk to or prejudiced the rights of BP so as to invalidate the indemnity. We do not believe that we breached our contract with BP Exploration or committed an act that would otherwise invalidate the indemnity. The court’s rulings will be subject to appeal at the appropriate time.

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In responding to similar motions for summary judgment between Transocean and BP, the court also held that public policy would not bar Transocean’s claim for indemnification of compensatory damages, even if Transocean was found to be grossly negligent. The court also held, among other things, that Transocean’s contractual right to indemnity does not extend to punitive damages or civil penalties under the CWA.
The rulings in the MDL proceeding regarding the indemnities are based on maritime law and may not bind the determination of similar issues in lawsuits not comprising a part of the MDL proceedings. Accordingly it is possible that different conclusions with respect to indemnities will be reached by other courts.
Indemnification for criminal fines or penalties, if any, may not be available if a court were to find such indemnification unenforceable as against public policy. In addition, certain state laws, if deemed to apply, would not allow for enforcement of indemnification for gross negligence, and may not allow for enforcement of indemnification of persons who are found to be negligent with respect to personal injury claims.
BP’s public filings indicate that BP has recognized in excess of $40 billion in pre-tax charges, excluding offsets for settlement payments received from certain defendants in the proceedings described above under “Litigation,” as a result of the Macondo well incident. BP’s public filings also indicate that the amount of, among other things, certain natural resource damages with respect to certain OPA claims, some of which may be included in such charges, cannot be reliably estimated as of the dates of those filings.
In addition to the contractual indemnities discussed above, we have a general liability insurance program of $600 million. Our insurance is designed to cover claims by businesses and individuals made against us in the event of property damage, injury or death and, among other things, claims relating to environmental damage, as well as legal fees incurred in defending against those claims. We have received and expect to continue to receive payments from our insurers with respect to covered legal fees incurred in connection with the Macondo well incident. Through June 2012, we have incurred legal fees and related expenses of approximately $117 million that have been reimbursed under or that are expected to be covered by our insurance program. To the extent we incur any losses beyond those covered by indemnification, there can be no assurance that our insurance policies will cover all potential claims and expenses relating to the Macondo well incident. In addition, we may not be insured with respect to civil or criminal fines or penalties, if any, pursuant to the terms of our insurance policies. Insurance coverage can be the subject of uncertainties and, particularly in the event of large claims, potential disputes with insurance carriers, as well as other potential parties claiming insured status under our insurance policies.
Barracuda-Caratinga arbitration
We provided indemnification in favor of KBR under the master separation agreement for all out-of-pocket cash costs and expenses (except for legal fees and other expenses of the arbitration so long as KBR controls and directs it), or cash settlements or cash arbitration awards, KBR may incur after November 20, 2006 as a result of the replacement of certain subsea flowline bolts installed in connection with the Barracuda-Caratinga project. At Petrobras’ direction, KBR replaced certain bolts located on the subsea flowlines that failed through mid-November 2005, and KBR informed us that additional bolts have failed thereafter, which were replaced by Petrobras. These failed bolts were identified by Petrobras when it conducted inspections of the bolts. In March 2006, Petrobras commenced arbitration against KBR claiming $220 million plus interest for the cost of monitoring and replacing the defective bolts and all related costs and expenses of the arbitration, including the cost of attorneys’ fees. During the third quarter of 2011, the arbitration panel issued an award against KBR in the amount of $201 million, which, along with accrued interest, is reflected as a liability in our condensed consolidated financial statements. Costs related to this matter are reflected as discontinued operations in our condensed consolidated financial statements. KBR filed a motion to vacate the arbitration award with the United States District Court for the Southern District of New York, and that motion is pending. See Note 5 for additional information regarding the KBR indemnification as well as an unrelated dispute with KBR related to the allocation of certain tax liabilities.
Securities and related litigation
In June 2002, a class action lawsuit was filed against us in federal court alleging violations of the federal securities laws after the Securities and Exchange Commission (SEC) initiated an investigation in connection with our change in accounting for revenue on long-term construction projects and related disclosures. In the weeks that followed, approximately twenty similar class actions were filed against us. Several of those lawsuits also named as defendants several of our present or former officers and directors. The class action cases were later consolidated, and the amended consolidated class action complaint, styled Richard Moore, et al. v. Halliburton Company, et al., was filed and served upon us in April 2003. As a result of a substitution of lead plaintiffs, the case was styled Archdiocese of Milwaukee Supporting Fund (AMSF) v. Halliburton Company, et al. AMSF has changed its name to Erica P. John Fund, Inc. (the Fund). We settled with the SEC in the second quarter of 2004.
In June 2003, the lead plaintiffs filed a motion for leave to file a second amended consolidated complaint, which was granted by the court. In addition to restating the original accounting and disclosure claims, the second amended consolidated complaint included claims arising out of our 1998 acquisition of Dresser Industries, Inc., including that we failed to timely disclose the resulting asbestos liability exposure.

15


In April 2005, the court appointed new co-lead counsel and named the Fund the new lead plaintiff, directing that it file a third consolidated amended complaint and that we file our motion to dismiss. The court held oral arguments on that motion in August 2005. In March 2006, the court entered an order in which it granted the motion to dismiss with respect to claims arising prior to June 1999 and granted the motion with respect to certain other claims while permitting the Fund to re-plead some of those claims to correct deficiencies in its earlier complaint. In April 2006, the Fund filed its fourth amended consolidated complaint. We filed a motion to dismiss those portions of the complaint that had been re-pled. A hearing was held on that motion in July 2006, and in March 2007 the court ordered dismissal of the claims against all individual defendants other than our Chief Executive Officer (CEO). The court ordered that the case proceed against our CEO and us.
In September 2007, the Fund filed a motion for class certification, and our response was filed in November 2007. The district court held a hearing in March 2008, and issued an order November 3, 2008 denying the motion for class certification. The Fund appealed the district court’s order to the Fifth Circuit Court of Appeals. The Fifth Circuit affirmed the district court’s order denying class certification. On May 13, 2010, the Fund filed a writ of certiorari in the United States Supreme Court. In early January 2011, the Supreme Court granted the writ of certiorari and accepted the appeal. The Court heard oral arguments in April 2011 and issued its decision in June 2011, reversing the Fifth Circuit ruling that the Fund needed to prove loss causation in order to obtain class certification. The Court’s ruling was limited to the Fifth Circuit’s loss causation requirement, and the case was returned to the Fifth Circuit for further consideration of our other arguments for denying class certification. The Fifth Circuit returned the case to the district court, and in January 2012 the court issued an order certifying the class. We filed a Petition for Leave to Appeal with the Fifth Circuit, which was granted and the case is stayed at the district court pending this appeal. In spite of its age, the case is at an early stage, and we cannot predict the outcome or consequences thereof. As of June 30, 2012, we had not accrued any amounts related to this matter because we do not believe that a loss is probable. Further, an estimate of possible loss or range of loss related to this matter cannot be made. We intend to vigorously defend this case.
Shareholder derivative cases
In May 2009, two shareholder derivative lawsuits involving us and KBR were filed in Harris County, Texas, naming as defendants various current and retired Halliburton directors and officers and current KBR directors. These cases allege that the individual Halliburton defendants violated their fiduciary duties of good faith and loyalty, to our detriment and the detriment of our shareholders, by failing to properly exercise oversight responsibilities and establish adequate internal controls. The District Court consolidated the two cases, and the plaintiffs filed a consolidated petition against only current and former Halliburton directors and officers containing various allegations of wrongdoing including violations of the United States Foreign Corrupt Practices Act (FCPA), claimed KBR offenses while acting as a government contractor in Iraq, claimed KBR offenses and fraud under United States government contracts, Halliburton activity in Iran, and illegal kickbacks. Subsequently, a shareholder made a demand that the Board take remedial action respecting the FCPA claims in the pending lawsuit. Our Board of Directors designated a special committee of certain independent and disinterested directors to oversee the investigation of the allegations made in the lawsuits and shareholder demand. Upon receipt of the special committee’s findings and recommendations, the independent and disinterested members of the Board determined that the shareholder claims were without merit and not otherwise in our best interest to pursue. The Board directed our counsel to report its determinations to the plaintiffs and demanding shareholder.
We have agreed in principle, subject to approval by the court, to settle the consolidated lawsuit and the process for seeking that approval is now underway. Under the terms of the proposed settlement, we have agreed to implement certain changes to our corporate governance policies and agreed to pay the plaintiffs’ legal fees. As of June 30, 2012, we have accrued for the plaintiffs’ legal fees, which are not material.
In February 2011, the same shareholder who had made the demand on our Board of Directors in connection with one of the derivative lawsuits discussed above filed a shareholder derivative lawsuit in Harris County, Texas naming us as a nominal defendant and certain of our directors and officers as defendants. This case alleges that these defendants, among other things, breached fiduciary duties of good faith and loyalty by failing to properly exercise oversight responsibilities and establish adequate internal controls, including controls and procedures related to cement testing and the communication of test results, as they relate to the Macondo well incident. Our Board of Directors designated a special committee of certain independent and disinterested directors to oversee the investigation of the allegations made in the lawsuit and shareholder demand. Upon receipt of the special committee’s findings and recommendations, the independent and disinterested members of the Board determined that the shareholder claims were without merit and not otherwise in our best interest to pursue. The Board directed our counsel to report its determinations to the plaintiffs and demanding shareholder.
We have agreed in principle, subject to approval by the court, to settle this lawsuit and the process for seeking that approval is now underway. Under the terms of the proposed settlement, we have agreed to implement certain changes to our corporate governance and health, safety, and environmental policies and agreed to pay the plaintiffs’ legal fees. As of June 30, 2012, we have accrued for the plaintiffs’ legal fees, which are not material.
Investigations
We are conducting internal investigations of certain areas of our operations in Angola and Iraq, focusing on compliance with certain company policies, including our Code of Business Conduct (COBC), and the FCPA and other applicable laws.

16


In December 2010, we received an anonymous e-mail alleging that certain current and former personnel violated our COBC and the FCPA, principally through the use of an Angolan vendor. The e-mail also alleges conflicts of interest, self-dealing, and the failure to act on alleged violations of our COBC and the FCPA. We contacted the DOJ to advise them that we were initiating an internal investigation.
Since the third quarter of 2011, we have been participating in meetings with the DOJ and the SEC to brief them on the status of our investigation and have been producing documents to them both voluntarily and as a result of SEC subpoenas to the company and certain of our current and former officers and employees.
During the second quarter of 2012, in connection with a meeting with the DOJ and the SEC regarding the above investigation, we advised the DOJ and the SEC that we were initiating unrelated, internal investigations into payments made to a third-party agent relating to certain customs matters in Angola and to third-party agents relating to certain customs and visa matters in Iraq.
We expect to continue to have discussions with the DOJ and the SEC regarding the Angola and Iraq matters described above and have indicated that we would further update them as our investigations progress. We have engaged outside counsel and independent forensic accountants to assist us with the investigations. We intend to continue to cooperate with the DOJ's and the SEC's inquiries and requests in these investigations. Because these investigations are ongoing, we cannot predict their outcome or the consequences thereof.
Environmental
We are subject to numerous environmental, legal, and regulatory requirements related to our operations worldwide. In the United States, these laws and regulations include, among others:
 
-
the Comprehensive Environmental Response, Compensation, and Liability Act;
 
-
the Resource Conservation and Recovery Act;
 
-
the Clean Air Act;
 
-
the Federal Water Pollution Control Act;
 
-
the Toxic Substances Control Act; and
 
-
the Oil Pollution Act of 1990.
In addition to the federal laws and regulations, states and other countries where we do business often have numerous environmental, legal, and regulatory requirements by which we must abide. We evaluate and address the environmental impact of our operations by assessing and remediating contaminated properties in order to avoid future liabilities and comply with environmental, legal, and regulatory requirements. Our Health, Safety and Environment group has several programs in place to maintain environmental leadership and to help prevent the occurrence of environmental contamination. On occasion, in addition to the matters relating to the Macondo well incident described above and the Duncan, Oklahoma matter described below, we are involved in other environmental litigation and claims, including the remediation of properties we own or have operated, as well as efforts to meet or correct compliance-related matters. We do not expect costs related to those remediation requirements to have a material adverse effect on our consolidated financial position or our results of operations. Excluding our loss contingency for the Macondo well incident, our accrued liabilities for environmental matters were $75 million as of June 30, 2012 and $81 million as of December 31, 2011. Because our estimated liability is typically within a range and our accrued liability may be the amount on the low end of that range, our actual liability could eventually be well in excess of the amount accrued. Our total liability related to environmental matters covers numerous properties.
Between approximately 1965 and 1991, one or more former Halliburton units performed work (as a contractor or subcontractor) for the U.S. Department of Defense cleaning solid fuel from missile motor casings at a semi-rural facility on the north side of Duncan, Oklahoma. In addition, from approximately November 1983 through December 1985, a discrete portion of the site was used to conduct a recycling project on stainless steel nuclear fuel rod racks from Omaha Public Power District’s Fort Calhoun Station. We closed the site in coordination with the Oklahoma Department of Environmental Quality (DEQ) in the mid-1990s, but continued to monitor the groundwater at the DEQ’s request. A principal component of the missile fuel was ammonium perchlorate, a salt that is highly soluble in water, which has been discovered in the soil and groundwater on our site and in certain residential water wells near our property. In August 2011, we entered into the DEQ’s Voluntary Cleanup Program and executed a voluntary Memorandum of Agreement and Consent Order for Site Characterization and Risk Based Remediation with the DEQ relating to the remediation of this site.

17


Commencing in October 2011, a number of lawsuits were filed against us, including a putative class action case in federal court in the Western District of Oklahoma and other lawsuits filed in Oklahoma state courts. The lawsuits generally allege, among other things, that operations at our Duncan facility caused releases of pollutants, including ammonium perchlorate and, in the case of the federal lawsuit, nuclear or radioactive waste, into the groundwater, and that we knew about those releases and did not take corrective actions to address them. It is also alleged that the plaintiffs have suffered from certain health conditions, including hypothyroidism, a condition that has been associated with exposure to perchlorate at sufficiently high doses over time. These cases seek, among other things, damages, including punitive damages, and the establishment of a fund for future medical monitoring. The cases allege, among other things, strict liability, trespass, private nuisance, public nuisance, and negligence and, in the case of the federal lawsuit, violations of the U.S. Resource Conservation and Recovery Act (RCRA), resulting in personal injuries, property damage, and diminution of property value.
The lawsuits generally allege that the cleaning of the missile casings at the Duncan facility contaminated the surrounding soils and groundwater, including certain water wells used in a number of residential homes, through the migration of, among other things, ammonium perchlorate. The federal lawsuit also alleges that our processing of radioactive waste from a nuclear power plant over 25 years ago resulted in the release of “nuclear/radioactive” waste into the environment. In April 2012, the judge in the federal lawsuit dismissed the plaintiffs’ RCRA claim. The other claims brought in that lawsuit remain pending.
To date, soil and groundwater sampling relating to the allegations discussed above has confirmed that the alleged nuclear or radioactive material is confined to the soil in a discrete area of the onsite operations and is not presently believed to be in the groundwater onsite or in any areas offsite. The radiological impacts from this discrete area are not believed to present any health risk for offsite exposure. With respect to ammonium perchlorate, we have made arrangements to supply affected residents with bottled drinking water and, if needed, with access to temporary public water supply lines, at no cost to the residents. We have worked with the City of Duncan and the DEQ to expedite expansion of the city water supply to the relevant areas at our expense.
The lawsuits described above are at an early stage, and additional lawsuits and proceedings may be brought against us. We cannot predict their outcome or the consequences thereof. As of June 30, 2012, we had accrued $29 million related to our initial estimate of response efforts, third-party property damage, and remediation related to the Duncan, Oklahoma matter. We intend to vigorously defend the lawsuits and do not believe that these lawsuits will have a material adverse effect on our liquidity, consolidated results of operations, or consolidated financial condition.
Additionally, we have subsidiaries that have been named as potentially responsible parties along with other third parties for 10 federal and state superfund sites for which we have established reserves. As of June 30, 2012, those 10 sites accounted for approximately $6 million of our $75 million total environmental reserve. Despite attempts to resolve these superfund matters, the relevant regulatory agency may at any time bring suit against us for amounts in excess of the amount accrued. With respect to some superfund sites, we have been named a potentially responsible party by a regulatory agency; however, in each of those cases, we do not believe we have any material liability. We also could be subject to third-party claims with respect to environmental matters for which we have been named as a potentially responsible party.
Guarantee arrangements
In the normal course of business, we have agreements with financial institutions under which approximately $1.8 billion of letters of credit, bank guarantees, or surety bonds were outstanding as of June 30, 2012, including $284 million of surety bonds related to Venezuela. Some of the outstanding letters of credit have triggering events that would entitle a bank to require cash collateralization. 

18


Note 7. Income per Share
Basic income per share is based on the weighted average number of common shares outstanding during the period. Diluted income per share includes additional common shares that would have been outstanding if potential common shares with a dilutive effect had been issued.
A reconciliation of the number of shares used for the basic and diluted income per share calculations is as follows:

 
 
Three Months Ended
June 30
 
Six Months Ended
June 30
Millions of shares
 
2012
 
2011
 
2012
 
2011
Basic weighted average common shares outstanding
 
924

 
916

 
923

 
915

Dilutive effect of employee stock plans
 
2

 
5

 
3

 
5

Diluted weighted average common shares outstanding
 
926

 
921

 
926

 
920


Excluded from the computation of diluted income per share are options to purchase ten million and seven million shares of common stock that were outstanding during the three and six months ended June 30, 2012 and two million and one million shares that were outstanding during the three and six months ended June 30, 2011. These options were outstanding during these periods but were excluded because they were antidilutive, as the option exercise price was greater than the average market price of the common shares.

Note 8. Fair Value of Financial Instruments
At June 30, 2012, we held $50 million of non-cash equivalents in United States Treasury securities with maturities that extend through July 2012 classified as short-term marketable securities. These securities are accounted for as available-for-sale and recorded at fair value, based on quoted market prices. The carrying amount of cash and equivalents, receivables, and accounts payable, as reflected in the condensed consolidated balance sheets, approximates fair value due to the short maturities of these instruments. We have no financial instruments measured at fair value using unobservable inputs.
The fair value of our long-term debt was $6.3 billion as of June 30, 2012 and $6.2 billion as of December 31, 2011, which differs from the carrying amount of $4.8 billion as of both June 30, 2012 and December 31, 2011, on our condensed consolidated balance sheets. The fair value of our long-term debt was calculated using either quoted market prices or significant observable inputs for similar liabilities for the respective periods.
We hold a series of interest rate swaps relating to two of our debt instruments with a total notional amount of $1.0 billion at a weighted-average, LIBOR-based, floating rate of 3.5% as of June 30, 2012. We utilize interest rate swaps to effectively convert a portion of our fixed rate debt to floating rates. These interest rate swaps, which expire when the underlying debt matures, are designated as fair value hedges of the underlying debt and are determined to be highly effective. The fair value of our interest rate swaps is included in “Other assets” in our condensed consolidated balance sheets as of June 30, 2012 and December 31, 2011. The fair value of our interest rate swaps was determined using an income approach model with inputs, such as the notional amount, LIBOR rate spread, settlement terms, and counterparty credit risk, that are observable in the market or can be derived from or corroborated by observable data. These derivative instruments are marked to market with gains and losses recognized currently in interest expense to offset the respective gains and losses recognized on changes in the fair value of the hedged debt. At June 30, 2012, we had fixed rate debt aggregating $3.8 billion and variable rate debt aggregating $1.0 billion, after taking into account the effects of the interest rate swaps. The fair value of our interest rate swaps was not material as of June 30, 2012.

Note 9. Accounting Standards Recently Adopted
On January 1, 2012, we adopted an update issued by the Financial Accounting Standards Board (FASB) to existing guidance on the presentation of comprehensive income. This update requires the presentation of the components of net income and other comprehensive income either in a single continuous statement or in two separate but consecutive statements. The requirement to present reclassification adjustments for items that are reclassified from other comprehensive income to net income on the face of the financial statement has been deferred by the FASB. Net income and other comprehensive income has been presented in two separate but consecutive statements for the current reporting period and prior comparative period in our condensed consolidated financial statements.

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

EXECUTIVE OVERVIEW

Organization
We are a leading provider of services and products to the energy industry. We serve the upstream oil and natural gas industry throughout the lifecycle of the reservoir, from locating hydrocarbons and managing geological data, to drilling and formation evaluation, well construction and completion, and optimizing production through the life of the field. Activity levels within our operations are significantly impacted by spending on upstream exploration, development, and production programs by major, national, and independent oil and natural gas companies. We report our results under two segments, Completion and Production and Drilling and Evaluation:
 
-
our Completion and Production segment delivers cementing, stimulation, intervention, pressure control, specialty chemicals, artificial lift, and completion services. The segment consists of Halliburton Production Enhancement, Cementing, Completion Tools, Boots & Coots, and Multi-Chem; and
 
-
our Drilling and Evaluation segment provides field and reservoir modeling, drilling, evaluation, and precise wellbore placement solutions that enable customers to model, measure, and optimize their well construction activities. The segment consists of Halliburton Drill Bits and Services, Wireline and Perforating, Testing and Subsea, Baroid, Sperry Drilling, Landmark Software and Services, and Consulting and Project Management.
The business operations of our segments are organized around four primary geographic regions: North America, Latin America, Europe/Africa/CIS, and Middle East/Asia. We have significant manufacturing operations in various locations, including, but not limited to, the United States, Canada, the United Kingdom, Malaysia, Mexico, Brazil, and Singapore. With over 70,000 employees, we operate in approximately 80 countries around the world, and our corporate headquarters are in Houston, Texas and Dubai, United Arab Emirates.
Financial results
During the first half of 2012, we produced revenue of $14.1 billion and operating income of $2.2 billion, reflecting an operating margin of approximately 16%. Revenue increased $2.9 billion, or 26%, from the first half of 2011, while operating income increased $249 million, or 13%. These results were attributable to higher drilling activity in the oil and liquids-rich basins in North America, as well as increased activity in all our international regions, compared to the first half of 2011. The first half of 2012 results, however, were moderated by escalating costs associated with guar gum, a blending additive used in our hydraulic fracturing processes, decreasing activity in natural gas basins, and pricing pressure in certain basins in North America due to an over-supply of hydraulic fracturing equipment. The first half of 2012 results included a $300 million, pre-tax, loss contingency for the Macondo well incident. The first half of 2011 results were negatively impacted by an $11 million, pre-tax, charge for employee separation costs in the Eastern Hemisphere and a $59 million, pre-tax, charge in Libya, primarily related to reserves for certain assets.
Business outlook
We continue to believe in the strength of the long-term fundamentals of our business. Energy demand is expected to increase in the long term driven by economic growth in developing countries despite current underlying downside risks in the industry, such as sluggish growth in developed countries and supply uncertainties associated with geopolitical tensions in the Middle East. Furthermore, development of new resources is expected to be more complex resulting in increasing service intensity.
In North America, the industry is experiencing a shift from natural gas shale plays to oil and liquids-rich shale plays due to low natural gas prices resulting from continued strong natural gas production despite peak natural gas storage levels. We believe we will continue to see a modest reduction in natural gas drilling over the remainder of the year as operators optimize their budgets by focusing on basins with better economics. While oil and liquids-rich drilling has mostly offset the decline in the first half of 2012, we believe the recent volatility in oil prices and softness in natural gas liquids prices may prompt certain customers to adopt a more cautious tone for the remainder of 2012. We anticipate near-term pricing pressure for our production enhancement services in certain markets and continued cost inflation related to guar gum.
Our Gulf of Mexico business continues to recover due to an increase in the level of permit approvals for deepwater drilling. We remain optimistic about the recovery of activity in the Gulf of Mexico as our customers adapt to new regulations and new permit approvals are issued. In addition, more deepwater rigs are expected to arrive in the Gulf of Mexico over the course of this year. We believe that an increasing pace of permit applications and approvals needs to be sustained in order for the Gulf of Mexico business to recover to activity levels experienced before the Macondo well incident. See “Business Environment and Results of Operations.”

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Outside of North America, revenue and operating income increased in the first half of 2012 compared to the first half of 2011.We believe competitive pricing for large, long-term international projects will continue throughout 2012. However, for the remainder of the year, we expect to see gradual activity improvements as new rigs, particularly in deepwater, enter the international markets. We also believe that new international unconventional oil and natural gas projects may contribute to activity improvements this year. Recently, our operations in Egypt have recovered from the turmoil experienced in the first quarter of 2011. Although some minor work has been performed in Libya, we are still awaiting well-defined operational plans from our customers. We do not expect activity levels in Libya to recover to pre-2011 levels until late 2012 or 2013.
We are continuing to execute several key initiatives in 2012. These initiatives include increasing manufacturing production in the Eastern Hemisphere and reinventing our service delivery platform to lower our delivery costs.
Our operating performance and business outlook are described in more detail in “Business Environment and Results of Operations.”
Financial markets, liquidity, and capital resources
The global financial markets continue to be somewhat volatile. While this has created additional risks for our business, we believe we have invested our cash balances conservatively and secured sufficient financing to help mitigate any near-term negative impact on our operations. For additional information, see “Liquidity and Capital Resources” and “Business Environment and Results of Operations.”



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LIQUIDITY AND CAPITAL RESOURCES

We ended the second quarter of 2012 and the year ended December 31, 2011 with cash and equivalents of $2.2 billion and $2.7 billion. As of June 30, 2012, approximately $416 million of the $2.2 billion of cash and equivalents was held by our foreign subsidiaries that would be subject to tax if repatriated. If these funds are needed for our operations in the United States, we would be required to accrue and pay United States taxes to repatriate these funds. However, our intent is to permanently reinvest these funds outside of the United States and our current plans do not demonstrate a need to repatriate them to fund our United States operations. We also held $50 million of short-term, United States Treasury securities at June 30, 2012 compared to $150 million at December 31, 2011 included in “Other current assets” on our condensed consolidated balance sheets.
Significant sources of cash
Cash flows from operating activities contributed $1.1 billion to cash in the first half of 2012.
During the first half of 2012, we sold or redeemed approximately $200 million of short-term marketable securities.
Significant uses of cash
Capital expenditures were $1.7 billion in the first half of 2012, and were predominantly made in Halliburton Production Enhancement, Sperry Drilling, Cementing, and Wireline and Perforating. We have also invested additional working capital to support the growth of our business.
During the first six months of 2012, inventories increased by $727 million, primarily because we procured a large reserve of guar gum when market prices were relatively high. See further discussion in "North America operations."
We paid $167 million in dividends to our shareholders in the first half of 2012.
During the first half of 2012, we purchased $100 million in short-term marketable securities.
Future uses of cash. Capital spending for 2012 is expected to range between $3.6 billion to $3.8 billion. The capital expenditures plan for 2012 is primarily directed toward Halliburton Production Enhancement, Sperry Drilling, Cementing, and Wireline and Perforating.
We are continuing to explore opportunities for acquisitions that will enhance or augment our current portfolio of services and products, including those with unique technologies or distribution networks in areas where we do not already have large operations.
Subject to Board of Directors approval, we expect to pay dividends of approximately $80 million per quarter during 2012. We also have approximately $1.7 billion remaining available under our share repurchase authorization, which may be used for open market share purchases.
Other factors affecting liquidity
Guarantee agreements. In the normal course of business, we have agreements with financial institutions under which an aggregate of approximately $1.8 billion of letters of credit, bank guarantees, or surety bonds were outstanding as of June 30, 2012, including $284 million of surety bonds related to Venezuela. See "Business Environment and Results of Operations - International Operations" for further discussion related to Venezuela. Some of the outstanding letters of credit have triggering events that would entitle a bank to require cash collateralization.
Financial position in current market. We have $2.2 billion of cash and equivalents and $50 million in investments in marketable securities as of June 30, 2012 and a total of $2.0 billion of available committed bank credit under our revolving credit facility. Furthermore, we have no financial covenants or material adverse change provisions in our bank agreements and our debt maturities extend over a long period of time. Although a portion of earnings from our foreign subsidiaries is reinvested outside the United States indefinitely, we do not consider this to have a significant impact on our liquidity. We currently believe that our capital expenditures, working capital investments, and dividends, if any, in 2012 can be fully funded through cash from operations.
As a result, we believe we have a reasonable amount of liquidity and, if necessary, additional financing flexibility given the current market environment to fund our potential contingent liabilities, if any. However, as discussed above in Note 6 to the condensed consolidated financial statements, there are numerous future developments that may arise as a result of the Macondo well incident that could have a material adverse effect on our liquidity.
Credit ratings. Credit ratings for our long-term debt remain A2 with Moody’s Investors Service and A with Standard & Poor’s. The credit ratings on our short-term debt remain P-1 with Moody’s Investors Service and A-1 with Standard & Poor’s.
Customer receivables. In line with industry practice, we bill our customers for our services in arrears and are, therefore, subject to our customers delaying or failing to pay our invoices. In weak economic environments, we may experience increased delays and failures to pay our invoices due to, among other reasons, a reduction in our customers’ cash flow from operations and their access to the credit markets. For example, we continue to see delays in receiving payment on our receivables from one of our primary customers in Venezuela. If our customers delay in paying or fail to pay us a significant amount of our outstanding receivables, it could have a material adverse effect on our liquidity, consolidated results of operations, and consolidated financial condition.



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BUSINESS ENVIRONMENT AND RESULTS OF OPERATIONS

We operate in approximately 80 countries to provide a comprehensive range of discrete and integrated services and products to the energy industry. The majority of our consolidated revenue is derived from the sale of services and products to major, national, and independent oil and natural gas companies worldwide. We serve the upstream oil and natural gas industry throughout the lifecycle of the reservoir, from locating hydrocarbons and managing geological data, to drilling and formation evaluation, well construction and completion, and optimizing production throughout the life of the field. Our two business segments are the Completion and Production segment and the Drilling and Evaluation segment. The industries we serve are highly competitive with many substantial competitors in each segment. In the first half of 2012, based upon the location of the services provided and products sold, 56% of our consolidated revenue was from the United States. In the first half of 2011, 54% of our consolidated revenue was from the United States. No other country accounted for more than 10% of our revenue during these periods.
Operations in some countries may be adversely affected by unsettled political conditions, acts of terrorism, civil unrest, force majeure, war or other armed conflict, expropriation or other governmental actions, inflation, foreign currency exchange restrictions, and highly inflationary currencies. We believe the geographic diversification of our business activities reduces the risk that loss of operations in any one country, other than the United States, would be materially adverse to our consolidated results of operations.
Activity levels within our business segments are significantly impacted by spending on upstream exploration, development, and production programs by major, national, and independent oil and natural gas companies. Also impacting our activity is the status of the global economy, which impacts oil and natural gas consumption.
Some of the more significant measures of current and future spending levels of oil and natural gas companies are oil and natural gas prices, the world economy, the availability of credit, government regulation, and global stability, which together drive worldwide drilling activity. Our financial performance is significantly affected by oil and natural gas prices and worldwide rig activity, which are summarized in the following tables.
This table shows the average oil and natural gas prices for West Texas Intermediate (WTI), United Kingdom Brent crude oil, and Henry Hub natural gas:

 
 
Three Months Ended
 
Year Ended
 
 
June 30
 
December 31
Average Oil Prices (dollars per barrel)
 
2012
 
2011
 
2011
West Texas Intermediate
 
$
93.73

 
$
102.61

 
$
95.13

United Kingdom Brent
 
108.92

 
117.78

 
111.53

 
 
 
 
 
 
 
Average United States Natural Gas Prices (dollars per thousand cubic feet, or Mcf)
 
 

 
 

 
 

Henry Hub
 
$
2.26

 
$
4.38

 
$
4.09



    

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The quarterly and year-to-date average rig counts based on the Baker Hughes Incorporated rig count information were as follows:
 
 
Three Months Ended
June 30
 
Six Months Ended
June 30
Land vs. Offshore
 
2012
 
2011
 
2012
 
2011
United States:
 
 
 
 
 
 
 
 
Land
 
1,924

 
1,798

 
1,936

 
1,744

Offshore (incl. Gulf of Mexico)
 
46

 
32

 
44

 
29

Total
 
1,970

 
1,830

 
1,980

 
1,773

Canada:
 
 

 
 

 
 

 
 

Land
 
171

 
187

 
381

 
386

Offshore
 
2

 
1

 
2

 
1

Total
 
173

 
188

 
383

 
387

International (excluding Canada):
 
 

 
 

 
 

 
 

Land
 
923

 
847

 
901

 
854

Offshore
 
306

 
299

 
308

 
302

Total
 
1,229

 
1,146

 
1,209

 
1,156

Worldwide total
 
3,372

 
3,164

 
3,572

 
3,316

Land total
 
3,018

 
2,832

 
3,218

 
2,984

Offshore total
 
354

 
332

 
354

 
332

 
 
 
 
 
 
 
 
 
 
 
Three Months Ended
June 30
 
Six Months Ended
June 30
Oil vs. Natural Gas
 
2012
 
2011
 
2012
 
2011
United States (incl. Gulf of Mexico):
 
 

 
 

 
 
 
 

Oil
 
1,372

 
946

 
1,317

 
879

Natural gas
 
598

 
884

 
663

 
894

Total
 
1,970

 
1,830

 
1,980

 
1,773

Canada:
 
 

 
 

 
 

 
 

Oil
 
118

 
114

 
271

 
258

Natural gas
 
55

 
74

 
112

 
129

Total
 
173

 
188

 
383

 
387

International (excluding Canada):
 
 

 
 

 
 

 
 

Oil
 
980

 
894

 
961

 
902

Natural gas
 
249

 
252

 
248

 
254

Total
 
1,229

 
1,146

 
1,209

 
1,156

Worldwide total
 
3,372

 
3,164

 
3,572

 
3,316

Oil total
 
2,470

 
1,954

 
2,549

 
2,039

Natural gas total
 
902

 
1,210

 
1,023

 
1,277

 
 
Three Months Ended
June 30
 
Six Months Ended
June 30
Drilling Type
 
2012
 
2011
 
2012
 
2011
United States (incl. Gulf of Mexico):
 
 
 
 
 
 
 
 
Horizontal
 
1,169

 
1,039

 
1,170

 
1,009

Vertical
 
569

 
561

 
585

 
538

Directional
 
232

 
230

 
225

 
226

Total
 
1,970

 
1,830

 
1,980

 
1,773

    

24


Our customers’ cash flows, in most instances, depend upon the revenue they generate from the sale of oil and natural gas. Lower oil and natural gas prices usually translate into lower exploration and production budgets. The opposite is true for higher oil and natural gas prices.
WTI oil spot prices fluctuated throughout 2011 between a low of approximately $75 per barrel to a high of approximately $113 per barrel. Brent oil spot prices fluctuated between a low of approximately $94 per barrel to a high of approximately $127 per barrel during this same period. During the first half of 2012, WTI and Brent oil spot prices averaged approximately $98 and $113 per barrel, respectively, consistent with prices experienced in the first half of 2011. Significant decreases, however, have occurred in the second quarter of 2012 as geopolitical tension in the Middle East, global economic uncertainty surrounding the European debt crisis, and the threat of a slowdown in the Chinese economy have impacted demand. The outlook for world petroleum demand for the remainder of 2012 remains mixed, with the International Energy Agency’s July 2012 “Oil Market Report” continuing to forecast 2012 demand to increase approximately 1% over 2011 levels.
Natural gas prices in the United States have declined approximately 45% from the first half of 2011 due to the resiliency of natural gas production coupled with natural gas inventories above five-year historical levels. In response, our customers have curtailed natural gas drilling activity. Despite recent improvement in spot prices, we believe that downward pressure on natural gas prices will continue through the summer injection season. The United States Energy Information Administration's July 2012 “Short Term Energy Outlook” forecast a continued shift in electricity generation from coal to natural gas, but we foresee significant price constraints in the near-term as natural gas competes as a fuel source in the power generation market.
In spite of this tempered outlook, we believe that, over the long term, hydrocarbon demand will generally increase. Increased demand, combined with the underlying trends of smaller and more complex reservoirs, high depletion rates, and the need for continual reserve replacement, should drive the long-term need for our services and products.
North America operations
Depressed natural gas prices can impact our customers’ drilling and production activities, particularly in North America. The decline in natural gas prices compared to the first half of 2011 has accelerated the shift from natural gas shale plays to oil and liquids-rich shale plays. For the first half of 2012, the average natural gas directed rig count fell by 248 rigs, or 24%, from the first half of 2011, while the average oil directed rig count has increased by 460 rigs, or 41%, over the same period. This transition has resulted in additional relocation costs and inefficiencies, which negatively impacted our margins in the first half of 2012. Increased costs for certain raw materials, particularly for guar gum, also adversely affected our margins in the second quarter of 2012. The seasonal Canadian spring break-up, a period when road conditions hinder the movement of heavy equipment, had a negative impact on our results in the second quarter of 2012 due to the growth we have experienced in this market in recent years. We anticipate that this market will recover in the second half of the year as road conditions improve. In the long run, we believe the shift to oil and liquids-rich shale basins will continue to drive increased service intensity, but also in fluid chemistry and other technologies required for these complex reservoirs. Production enhancement pricing, however, may be challenging as competition increases in these oil and liquids-rich plays and our contracts come up for renewal.
In May 2010, the United States Department of the Interior effectively suspended all offshore deepwater drilling projects in the United States Gulf of Mexico. The suspension was lifted in October 2010, but permits were not issued for an extended period of time, and we experienced a significant reduction in our Gulf of Mexico operations. In the first quarter of 2011, the issuance of drilling permits resumed. Deepwater drilling activity in the Gulf of Mexico continues to recover due to an increase in drilling permit approvals. We believe we will see an increase in the level of permit approvals through the remainder of 2012, leading to additional deepwater rigs arriving in the Gulf of Mexico. Over the long term, our results in the Gulf of Mexico are dependent on, among other things, governmental approvals for permits, our customers’ actions, and the potential movement of deepwater rigs to or from other markets.
International operations
In 2011, pricing pressures from over capacity and geopolitical disruptions in North Africa had a negative impact on international operating income. In the second half of 2012 and into 2013, we continue to anticipate that the industry will experience steady volume increases as macroeconomic trends support a more favorable operator spending outlook and new rigs are scheduled to enter the market. We believe these trends will eventually lead to meaningful absorption of equipment supply. The average international rig count has improved by 53 rigs, or 5%, since the first half of 2011. Despite this increased volume, we continue to believe that international pricing will remain competitive, particularly for larger projects. We also believe that international unconventional oil and natural gas and deepwater projects will contribute to activity improvements, and we plan to leverage our extensive experience in North America to optimize these opportunities. Consistent with our long-term strategy to grow our operations outside of North America, we also expect to continue to invest capital in our international operations.
Venezuela. As of June 30, 2012, our total net investment in Venezuela was approximately $247 million. In addition to this amount, we have $284 million of surety bond guarantees outstanding relating to our Venezuelan operations.


25



Initiatives
Following is a brief discussion of some of our recent and current initiatives:
-
increasing our market share in the more economic, unconventional plays, mature fields, and deepwater markets by leveraging our broad technology offerings to provide value to our customers through integrated solutions and the ability to more efficiently drill and complete their wells;
-
exploring opportunities for acquisitions that will enhance or augment our current portfolio of services and products, including those with unique technologies or distribution networks in areas where we do not already have large operations;
-
making key investments in technology and capital to accelerate growth opportunities. To that end, we are continuing to push our technology and manufacturing development, as well as our supply chain, closer to our customers in the Eastern Hemisphere;
-
improving working capital, and managing our balance sheet to maximize our financial flexibility. We are deploying a global project to improve service delivery that we expect to result in, among other things, additional investments in our systems and significant improvements to our current order-to-cash and purchase-to-pay processes;
-
continuing to seek ways to be one of the most cost efficient service providers in the industry by using our scale and breadth of operations; and
-
expanding our business with national oil companies.

26


RESULTS OF OPERATIONS IN 2012 COMPARED TO 2011

Three Months Ended June 30, 2012 Compared with Three Months Ended June 30, 2011

REVENUE:
 
Three Months Ended
June 30
 
Favorable
 
Percentage
Millions of dollars
 
2012
 
2011
 
(Unfavorable)
 
Change
Completion and Production
 
$
4,460

 
$
3,618

 
$
842

 
23
%
Drilling and Evaluation
 
2,774

 
2,317

 
457

 
20

Total revenue
 
$
7,234

 
$
5,935

 
$
1,299

 
22
%

By geographic region:
Completion and Production:
 
 
 
 
 
 
 
 
North America
 
$
3,167

 
$
2,588

 
$
579

 
22
%
Latin America
 
340

 
268

 
72

 
27

Europe/Africa/CIS
 
551

 
415

 
136

 
33

Middle East/Asia
 
402

 
347

 
55

 
16

Total
 
4,460

 
3,618

 
842

 
23

Drilling and Evaluation:
 
 

 
 

 
 

 
 

North America
 
973

 
857

 
116

 
14

Latin America
 
539

 
419

 
120

 
29

Europe/Africa/CIS
 
605

 
554

 
51

 
9

Middle East/Asia
 
657

 
487

 
170

 
35

Total
 
2,774

 
2,317

 
457

 
20

Total revenue by region:
 
 

 
 

 
 

 
 

North America
 
4,140

 
3,445

 
695

 
20

Latin America
 
879

 
687

 
192

 
28

Europe/Africa/CIS
 
1,156

 
969

 
187

 
19

Middle East/Asia
 
1,059

 
834

 
225

 
27

















27


OPERATING INCOME:
 
Three Months Ended
June 30
 
Favorable
 
Percentage
Millions of dollars
 
2012
 
2011
 
(Unfavorable)
 
Change
Completion and Production
 
$
914

 
$
918

 
$
(4
)
 
 %
Drilling and Evaluation
 
393

 
324

 
69

 
21

Corporate and other
 
(106
)
 
(81
)
 
(25
)
 
31

Total operating income
 
$
1,201

 
$
1,161

 
$
40

 
3
 %

By geographic region:
Completion and Production:
 
 
 
 
 
 
 
 
North America
 
$
691

 
$
827

 
$
(136
)
 
(16
)%
Latin America
 
54

 
29

 
25

 
86

Europe/Africa/CIS
 
95

 
15

 
80

 
533

Middle East/Asia
 
74

 
47

 
27

 
57

Total
 
914

 
918

 
(4
)
 

Drilling and Evaluation:
 
 

 
 

 
 

 
 

North America
 
166

 
170

 
(4
)
 
(2
)
Latin America
 
84

 
52

 
32

 
62

Europe/Africa/CIS
 
64

 
53

 
11

 
21

Middle East/Asia
 
79

 
49

 
30

 
61

Total
 
393

 
324

 
69

 
21

Total operating income by region
 
 

 
 

 
 

 
 

(excluding Corporate and other):
 
 
 
 
 
 
 
 
North America
 
857

 
997

 
(140
)
 
(14
)
Latin America
 
138

 
81

 
57

 
70

Europe/Africa/CIS
 
159

 
68

 
91

 
134

Middle East/Asia
 
153

 
96

 
57

 
59

    
The 22% increase in consolidated revenue in the second quarter of 2012 compared to the second quarter of 2011 was primarily attributable to increased activity in the United States, as the demand for production enhancement, completion tools, and cementing work continued to rise. On a consolidated basis, all product service lines experienced revenue growth from the second quarter of 2011. Revenue outside of North America was 43% of consolidated revenue in the second quarter of 2012 and 42% of consolidated revenue in the second quarter of 2011.
The 3% increase in consolidated operating income during the second quarter of 2012 compared to the second quarter of 2011 was driven by strong international results, particularly in the Europe/Africa/CIS region, which were offset by rising costs and pricing pressure for production enhancement services in the more service intensive, unconventional oil and liquids-rich basins in the United States land market. Operating income in the second quarter of 2011 was adversely impacted by $11 million, pre-tax, of employee separation costs in the Eastern Hemisphere.
Following is a discussion of our results of operations by reportable segment.
Completion and Production consolidated revenue increased 23% and North America revenue increased 22% compared to the second quarter of 2011, led by production enhancement services as higher activity in unconventional basins generally resulted in increased demand for pressure-pumping services. Latin America revenue grew 27%, with higher demand for production enhancement services in Mexico and cementing services in Brazil. Europe/Africa/CIS revenue increased 33%, driven by strong demand for completion tools and pressure-pumping services in Angola, additional work in Mozambique, and higher cementing activity in Norway. Middle East/Asia revenue grew 16%, driven by higher activity levels in Oman, Australia, and Southeast Asia, which were partially offset by lower product sales in China. Revenue outside of North America was 29% of total segment revenue in the second quarter of 2012 and 28% of total segment revenue in the second quarter of 2011.

28


Completion and Production segment operating income was essentially flat compared to the second quarter of 2011, as increased costs and price erosion for production enhancement services in the United States land market were offset by higher demand for cementing services and completion tools worldwide. The second quarter of 2011 results were negatively impacted by $6 million, pre-tax, of employee separation costs in the Eastern Hemisphere. In North America, operating income decreased 16% compared to the second quarter of 2011 due to increased costs, particularly for guar gum, and pricing pressure in production enhancement services in the United States land market. Latin America operating income grew 86% as a result of increased demand for production enhancement services in Mexico and cementing services in Brazil, as well as higher activity levels in Venezuela. Europe/Africa/CIS operating income improved by $80 million due to higher activity levels in Nigeria and the Caspian, as well as additional completion tools sales in Angola. Middle East/Asia operating income increased 57% due to cost controls in Iraq, higher cementing activity in Oman, and increased completion tools activity in Southeast Asia.
Drilling and Evaluation revenue increased 20% compared to the second quarter of 2011, with all regions experiencing revenue growth. North America revenue increased 14%, primarily due to higher drilling fluids demand in the United States. Latin America revenue was up 29%, driven by higher activity in Brazil, Mexico, and Colombia. Europe/Africa/CIS revenue increased 9% due to higher activity levels in Tanzania, direct sales in Poland, and increased demand for drilling services in Angola. Middle East/Asia revenue grew 35%, primarily due to increased activity levels in Malaysia, Iraq, and China and direct sales in Saudi Arabia, which were partially offset by lower drilling activity in Indonesia. Revenue outside of North America was 65% of total segment revenue in the second quarter of 2012 and 63% of total segment revenue in the second quarter of 2011.
Drilling and Evaluation operating income increased 21% compared to the second quarter of 2011, as profitability improved in all international regions. The second quarter of 2011 results were negatively impacted by $5 million, pre-tax, of employee separation costs in the Eastern Hemisphere. North America operating income was essentially flat, as increases in drill bit services were offset by increased costs in the United States land market. Latin America operating income improved 62%, driven by strong demand for testing and subsea services in Brazil, higher activity levels in Colombia and Venezuela. Europe/Africa/CIS operating income increased 21% as a result of higher activity in Nigeria and the Caspian region, which more than offset increased costs in Norway. Middle East/Asia operating income grew 61%, primarily due to increased wireline activity in Saudi Arabia and higher product sales and cost reductions in China.
Corporate and other expenses increased $25 million in the second quarter of 2012 compared to the second quarter of 2011, primarily due to higher legal costs and additional expenses associated with strategic investments in our operating model and creating competitive advantage by repositioning our technology, supply chain, and manufacturing infrastructure.

NONOPERATING ITEMS
Interest expense, net of interest income increased $17 million in the second quarter of 2012 compared to the second quarter of 2011, primarily due to the issuance of $1.0 billion senior notes in November 2011.



29


Six Months Ended June 30, 2012 Compared with Six Months Ended June 30, 2011

REVENUE:
 
Six Months Ended
June 30
 
Favorable
 
Percentage
Millions of dollars
 
2012
 
2011
 
(Unfavorable)
 
Change
Completion and Production
 
$
8,750

 
$
6,790

 
$
1,960

 
29
%
Drilling and Evaluation
 
5,352

 
4,427

 
925

 
21

Total revenue
 
$
14,102

 
$
11,217

 
$
2,885

 
26
%

By geographic region:
Completion and Production:
 
 
 
 
 
 
 
 
North America
 
$
6,349

 
$
4,809

 
$
1,540

 
32
%
Latin America
 
646

 
508

 
138

 
27

Europe/Africa/CIS
 
1,007

 
816

 
191

 
23

Middle East/Asia
 
748

 
657

 
91

 
14

Total
 
8,750

 
6,790

 
1,960

 
29

Drilling and Evaluation:
 
 

 
 

 
 

 
 

North America
 
1,959

 
1,618

 
341

 
21

Latin America
 
1,013

 
791

 
222

 
28

Europe/Africa/CIS
 
1,161

 
1,064

 
97

 
9

Middle East/Asia
 
1,219

 
954

 
265

 
28

Total
 
5,352

 
4,427

 
925

 
21

Total revenue by region:
 
 

 
 

 
 

 
 

North America
 
8,308

 
6,427

 
1,881

 
29

Latin America
 
1,659

 
1,299

 
360

 
28

Europe/Africa/CIS
 
2,168

 
1,880

 
288

 
15

Middle East/Asia
 
1,967

 
1,611

 
356

 
22

























30


OPERATING INCOME:
 
Six Months Ended
June 30
 
Favorable
 
Percentage
Millions of dollars
 
2012
 
2011
 
(Unfavorable)
 
Change
Completion and Production
 
$
1,950

 
$
1,578

 
$
372

 
24
%
Drilling and Evaluation
 
761

 
554

 
207

 
37

Corporate and other
 
(487
)
 
(157
)
 
(330
)
 
210

Total operating income
 
$
2,224

 
$
1,975

 
$
249

 
13
%

By geographic region:
Completion and Production:
 
 
 
 
 
 
 
 
North America
 
$
1,562

 
$
1,441

 
$
121

 
8
%
Latin America
 
109

 
65

 
44

 
68

Europe/Africa/CIS
 
152

 
(11
)
 
163

 
1,482

Middle East/Asia
 
127

 
83

 
44

 
53

Total
 
1,950

 
1,578

 
372

 
24

Drilling and Evaluation:
 
 

 
 

 
 

 
 

North America
 
356

 
288

 
68

 
24

Latin America
 
151

 
92

 
59

 
64

Europe/Africa/CIS
 
104

 
75

 
29

 
39

Middle East/Asia
 
150

 
99

 
51

 
52

Total
 
761

 
554

 
207

 
37

Total operating income by region
 
 

 
 

 
 

 
 

(excluding Corporate and other):
 
 
 
 
 
 
 
 
North America
 
1,918

 
1,729

 
189

 
11

Latin America
 
260

 
157

 
103

 
66

Europe/Africa/CIS
 
256

 
64

 
192

 
300

Middle East/Asia
 
277

 
182

 
95

 
52