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Press release from PR Newswire

Baker Hughes Announces Second Quarter Results

Friday, July 19, 2013

Baker Hughes Announces Second Quarter Results

06:00 EDT Friday, July 19, 2013

HOUSTON, July 19, 2013 /PRNewswire/ -- Baker Hughes Incorporated (NYSE:  BHI) announced today net income on a GAAP basis for the second quarter of 2013 of $240 million or $0.54 per diluted share.  This includes after-tax charges of $20 million ($0.05 per diluted share) for bad debt provisions in Latin America and $7 million ($0.02 per diluted share) for an inventory charge related to certain proppants used in pressure pumping in North America.  These results compare to net income of $0.60 per diluted share for the first quarter of 2013, and $1.00 per diluted share for the second quarter of 2012.

Revenue for the second quarter of 2013 was $5.49 billion, up 5% compared to $5.23 billion for the first quarter of 2013 and up 3% compared to $5.33 billion for the second quarter of 2012.

"Our second quarter results reflect mixed performance across our international operating segments," said Martin Craighead, Baker Hughes' Chairman and Chief Executive Officer.  "Activity levels continued to rise across the Eastern Hemisphere based on strong demand in deepwater markets, particularly in Europe and Africa, as well as seasonal improvements in Russia.  However, our gains in the East were more than offset by a sharp decline in Latin America resulting from reduced activity and demobilization costs in Brazil and Mexico.  In response to these conditions, during the second quarter we began taking actions to reduce costs in our Latin America operations.  This process should be substantially complete in the third quarter leading to increased profitability in the second half of the year."

Craighead added, "Our U.S. Pressure Pumping business continues to improve as recent share gains and operational improvements are increasing fleet utilization and profitability.  Combined with record performance from our Gulf of Mexico operations, revenue in North America grew 3% sequentially, despite Canadian seasonality reaching its lowest level in four years.  Now that Canada is returning to normal activity levels, we foresee a strong rebound in operating margins in the third quarter for North America."

Cash increased $22 million to $1.12 billion as of June 30, 2013, compared to $1.10 billion at March 31, 2013.  Debt decreased by $183 million to $4.91 billion compared to the first quarter of 2013.

Capital expenditures were $551 million, depreciation and amortization expense was $424 million and dividend payments were $66 million in the second quarter of 2013.

EBITDA in the second quarter of 2013 was $860 million, a decrease of $10 million compared to the first quarter of 2013.

 

Consolidated Condensed Statements of Income

(Unaudited)

Three Months Ended

June 30,

March 31,

(In millions, except per share amounts)

2013

2012

2013

Revenue

$

5,487

$

5,326

$

5,230

Costs and expenses:

Cost of revenue

4,591

4,254

4,326

Research and engineering

131

128

127

Marketing, general and administrative

329

305

322

   Total costs and expenses

5,051

4,687

4,775

Operating income

436

639

455

Interest expense, net

(60)

(50)

(55)

Income before income taxes

376

589

400

Income taxes

(131)

(151)

(132)

Net income

245

438

268

Net (income) loss attributable to noncontrolling interests

(5)

1

(1)

Net income attributable to Baker Hughes

$

240

$

439

$

267

Basic earnings per share attributable to Baker Hughes

$

0.54

$

1.00

$

0.60

Diluted earnings per share attributable to Baker Hughes

$

0.54

$

1.00

$

0.60

Weighted average shares outstanding, basic

443

439

443

Weighted average shares outstanding, diluted

444

440

444

Depreciation and amortization expense

$

424

$

380

$

415

Capital expenditures

$

551

$

771

$

490

 

Consolidated Condensed Statements of Income

(Unaudited)

Six Months Ended June 30,

(In millions, except per share amounts)

2013

2012

Revenue

$

10,717

$

10,681

Costs and expenses:

Cost of revenue

8,917

8,519

Research and engineering

258

252

Marketing, general and administrative

651

644

   Total costs and expenses

9,826

9,415

Operating income

891

1,266

Interest expense, net

(115)

(104)

Income before income taxes

776

1,162

Income taxes

(263)

(344)

Net income

513

818

Net income attributable to noncontrolling interests

(6)

?

Net income attributable to Baker Hughes

$

507

$

818

Basic earnings per share attributable to Baker Hughes

$

1.14

$

1.86

Diluted earnings per share attributable to Baker Hughes

$

1.14

$

1.86

Weighted average shares outstanding, basic

443

439

Weighted average shares outstanding, diluted

444

440

Depreciation and amortization expense

$

839

$

743

Capital expenditures

$

1,041

$

1,442

 

Consolidated Condensed Balance Sheets

(Unaudited)

June 30,

December 31,

(In millions)

2013

2012

ASSETS

Current Assets:

Cash and cash equivalents

$

1,123

$

1,015

Accounts receivable - less allowance for doubtful accounts

(2013 - $274,  2012 - $308)

5,197

4,815

Inventories, net

3,838

3,781

Other current assets

772

806

   Total current assets

10,930

10,417

Property, plant and equipment, net

8,855

8,707

Goodwill

5,954

5,958

Intangible assets, net

934

993

Other assets

677

614

Total assets

$

27,350

$

26,689

LIABILITIES AND EQUITY

Current Liabilities:

Accounts payable

$

2,211

$

1,737

Short-term debt and current portion of long-term debt

1,068

1,079

Accrued employee compensation

568

646

Other accrued liabilities

661

662

   Total current liabilities

4,508

4,124

Long-term debt

3,841

3,837

Deferred income taxes and other tax liabilities

674

745

Long-term liabilities

700

715

Equity

17,627

17,268

Total liabilities and equity

$

27,350

$

26,689

 

Consolidated Condensed Statements of Cash Flows

(Unaudited)

Six Months Ended June 30,

(In millions)

2013

2012

Cash flows from operating activities:

Net income

$

513

$

818

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

   Depreciation and amortization

839

743

   Other, primarily working capital

(274)

(1,437)

Net cash flows provided by operating activities

1,078

124

Cash flows from investing activities:

   Expenditures for capital assets

(1,041)

(1,442)

   Other

179

203

Net cash flows used in investing activities

(862)

(1,239)

Cash flows from financing activities:

   Net proceeds from issuance of debt

?

962

   Dividends

(132)

(131)

   Other

29

24

Net cash flows (used in) provided by financing activities

(103)

855

Effect of foreign exchange rate changes on cash

(5)

2

Increase (decrease) in cash and cash equivalents

108

(258)

Cash and cash equivalents, beginning of period

1,015

$

1,050

Cash and cash equivalents, end of period

$

1,123

$

792

 

Table 1: Reconciliation of GAAP and Non-GAAP Financial Measures

The following table reconciles net income attributable to Baker Hughes, which is the directly comparable financial result determined in accordance with Generally Accepted Accounting Principles (GAAP), to adjusted net income1 (a non-GAAP financial measure).  This excludes identified items with respect to the first quarter of 2013.  There were no identified items requiring adjustment for the second quarters of 2013 or 2012.

Three Months Ended March 31, 2013

(Unaudited)

(In millions, except per share amounts)

Net

Income

Diluted

Earnings

Per Share

Net income attributable to Baker Hughes (GAAP)

$

267

$

0.60

Identified Item:

Devaluation of Venezuelan currency2

23

0.05

Adjusted net income (non-GAAP)1

$

290

$

0.65

1

Adjusted net income is a non-GAAP measure comprised of net income attributable to Baker Hughes excluding the impact of certain identified items.  The Company believes that adjusted net income is useful to investors because it is a consistent measure of the underlying results of the Company's business.  Furthermore, management uses adjusted net income as a measure of the performance of the Company's operations.

2

Foreign exchange loss of $23 million before and after-tax due to the devaluation of Venezuela's currency from the prior exchange rate of 4.3 Bolivars Fuertes per U.S. Dollar to 6.3 Bolivars Fuertes per U.S. Dollar, which applied to our local currency denominated balances.

 

Table 2: Calculation of EBIT, EBITDA and Adjusted EBITDA (non-GAAP measures)1

Three Months Ended

June 30,

March 31,

(In millions)

2013

2012

2013

Net income attributable to Baker Hughes

$

240

$

439

$

267

Net income (loss) attributable to noncontrolling interests

5

(1)

1

Income taxes

131

151

132

Income before income taxes

376

589

400

Interest expense, net

60

50

55

Earnings before interest and taxes (EBIT)

436

639

455

Depreciation and amortization expense

424

380

415

Earnings before interest, taxes, depreciation and

amortization (EBITDA)

860

1,019

870

Adjustments to EBITDA:

Devaluation of Venezuelan currency2

?

?

23

Adjusted EBITDA

$

860

$

1,019

$

893

Six Months Ended June 30,

(In millions)

2013

2012

Net income attributable to Baker Hughes

$

507

$

818

Net income attributable to noncontrolling interests

6

?

Income taxes

263

344

Income before income taxes

776

1,162

Interest expense, net

115

104

Earnings before interest and taxes (EBIT)

891

1,266

Depreciation and amortization expense

839

743

Earnings before interest, taxes, depreciation and

amortization (EBITDA)

1,730

2,009

Adjustments to EBITDA:

Devaluation of Venezuelan currency2

23

?

Adjusted EBITDA

$

1,753

$

2,009

1

EBIT, EBITDA and Adjusted EBITDA (as defined in the calculations above) are non-GAAP measures.  Management is providing these measures because it believes that such measures are widely accepted financial indicators used by investors and analysts to analyze and compare companies on the basis of operating performance.

2

Foreign exchange loss of $23 million before and after-tax due to the devaluation of Venezuela's currency from the prior exchange rate of 4.3 Bolivars Fuertes per U.S. Dollar to 6.3 Bolivars Fuertes per U.S. Dollar, which applied to our local currency denominated balances.

 

Table 3a: Segment Revenue, Profit Before Tax, and Profit Before Tax Margin1

Three Months Ended

June 30,

March 31,

(In millions)

2013

2012

2013

Segment Revenue

North America

$

2,677

$

2,672

$

2,603

Latin America

557

604

590

Europe/Africa/Russia Caspian

966

925

854

Middle East/Asia Pacific

971

804

894

Industrial Services and Other

316

321

289

Total Operations

$

5,487

$

5,326

$

5,230

Profit Before Tax

North America

$

211

$

357

$

235

Latin America

(18)

77

49

Europe/Africa/Russia Caspian

151

156

93

Middle East/Asia Pacific

115

87

116

Industrial Services and Other

39

44

24

Total Operations

$

498

$

721

$

517

Corporate and Other Profit Before Tax

Interest expense, net

(60)

(50)

(55)

Corporate and other

(62)

(82)

(62)

Corporate, net interest and other

(122)

(132)

(117)

Profit Before Tax

$

376

$

589

$

400

Profit Before Tax Margin1

North America

8

%

13

%

9

%

Latin America

(3)

%

13

%

8

%

Europe/Africa/Russia Caspian

16

%

17

%

11

%

Middle East/Asia Pacific

12

%

11

%

13

%

Industrial Services and Other

12

%

14

%

8

%

Total Operations

9

%

14

%

10

%

1

Profit before tax margin is a non-GAAP measure defined as profit before tax ("income before income taxes") divided by revenue.  Management uses the profit before tax margin because it believes it is a widely accepted financial indicator used by investors and analysts to analyze and compare companies on the basis of operating performance.

 

Table 3b: Segment Revenue, Profit Before Tax, and Profit Before Tax Margin1

Six Months Ended June 30,

(In millions)

2013

2012

Segment Revenue

North America

$

5,280

$

5,535

Latin America

1,147

1,177

Europe/Africa/Russia Caspian

1,820

1,818

Middle East/Asia Pacific

1,865

1,549

Industrial Services and Other

605

602

Total Operations

$

10,717

$

10,681

Profit Before Tax

North America

$

446

$

758

Latin America

31

144

Europe/Africa/Russia Caspian

244

309

Middle East/Asia Pacific

231

162

Industrial Services and Other

63

66

Total Operations

$

1,015

$

1,439

Corporate and Other Profit Before Tax

Interest expense, net

(115)

(104)

Corporate and other

(124)

(173)

Corporate, net interest and other

(239)

(277)

Profit Before Tax

$

776

$

1,162

Profit Before Tax Margin1

North America

8

%

14

%

Latin America

3

%

12

%

Europe/Africa/Russia Caspian

13

%

17

%

Middle East/Asia Pacific

12

%

10

%

Industrial Services and Other

10

%

11

%

Total Operations

9

%

13

%

1

Profit before tax margin is a non-GAAP measure defined as profit before tax ("income before income taxes") divided by revenue.  Management uses the profit before tax margin because it believes it is a widely accepted financial indicator used by investors and analysts to analyze and compare companies on the basis of operating performance.

 

Table 4: Adjustments to Operating Profit Before Tax1

(In millions)

Three Months Ended

March 31, 2013

Six Months Ended

June 30, 2013

Adjustments to Operating Profit Before Tax

North America

$

?

$

?

Latin America2

23

23

Europe/Africa/Russia Caspian

?

?

Middle East/Asia Pacific

?

?

Industrial Services and Other

?

?

Total Operations

$

23

$

23

1

There were no items identified requiring adjustment in the second quarters of 2013 or 2012, nor in the first six months of 2012.

2

Foreign exchange loss of $23 million before-tax due to the devaluation of Venezuela's currency from the prior exchange rate of 4.3 Bolivars Fuertes per U.S. Dollar to 6.3 Bolivars Fuertes per U.S. Dollar, which applied to our local currency denominated balances.

 

Table 5a:  Supplemental Financial Information Excluding Certain Identified Items

The following table contains non-GAAP measures of operating profit before tax and operating profit before tax margin, excluding the $23 million charge for the devaluation of the Venezuelan currency recorded in the first quarter of 2013 (see Table 4).  There were no items requiring adjustment for the second quarters of 2013 or 2012.

Three Months Ended

June 30,

March 31,

(In millions)

2013

2012

2013

Segment Revenue

North America

$

2,677

$

2,672

$

2,603

Latin America

557

604

590

Europe/Africa/Russia Caspian

966

925

854

Middle East/Asia Pacific

971

804

894

Industrial Services and Other

316

321

289

Total Operations

$

5,487

$

5,326

$

5,230

Operating Profit Before Tax1

North America2

$

211

$

357

$

235

Latin America3

(18)

77

72

Europe/Africa/Russia Caspian

151

156

93

Middle East/Asia Pacific

115

87

116

Industrial Services and Other

39

44

24

Total Operations

$

498

$

721

$

540

Operating Profit Before Tax Margin1

North America2

8

%

13

%

9

%

Latin America3

(3)

%

13

%

12

%

Europe/Africa/Russia Caspian

16

%

17

%

11

%

Middle East/Asia Pacific

12

%

11

%

13

%

Industrial Services and Other

12

%

14

%

8

%

Total Operations

9

%

14

%

10

%

1

Operating profit before tax is a non-GAAP measure defined as profit before tax ("income before income taxes") less certain identified costs.  Operating profit before tax margin is a non-GAAP measure defined as operating profit before tax divided by revenue.  Management uses each of these measures because it believes they are widely accepted financial indicators used by investors and analysts to analyze and compare companies on the basis of operating performance and that these measures may be used by investors to make informed investment decisions.

2

Operating profit before tax and operating profit before tax margin include an inventory charge of $11 million (before-tax) related to certain proppants used in pressure pumping in North America in the second quarter 2013.

3

Operating profit before tax and operating profit before tax margin include bad debt provisions of $20 million (before and after-tax) in Latin America in the second quarter of 2013.

 

Table 5b:  Supplemental Financial Information Excluding Certain Identified Items

The following table contains non-GAAP measures of operating profit before tax and operating profit before tax margin, excluding the $23 million charge for the devaluation of the Venezuelan currency recorded in the first six months of 2013 (see Table 4).  There were no items requiring adjustment for the first six months of 2012.

Six Months Ended June 30,

(In millions)

2013

2012

Segment Revenue

North America

$

5,280

$

5,535

Latin America

1,147

1,177

Europe/Africa/Russia Caspian

1,820

1,818

Middle East/Asia Pacific

1,865

1,549

Industrial Services and Other

605

602

Total Operations

$

10,717

$

10,681

Operating Profit Before Tax1

North America2

$

446

$

758

Latin America3

54

144

Europe/Africa/Russia Caspian

244

309

Middle East/Asia Pacific

231

162

Industrial Services and Other

63

66

Total Operations

$

1,038

$

1,439

Operating Profit Before Tax Margin1

North America2

8

%

14

%

Latin America3

5

%

12

%

Europe/Africa/Russia Caspian

13

%

17

%

Middle East/Asia Pacific

12

%

10

%

Industrial Services and Other

10

%

11

%

Total Operations

10

%

13

%

See footnotes from Table 5a.

Baker Hughes Operational Highlights

The Baker Hughes FASTrak? logging while drilling (LWD) fluid analysis and sampling system launched in the second quarter 2013.  Since its introduction, Baker Hughes has successfully deployed FASTrak on wells for a customer in Australia.  The fluid sampling and formation pressure testing capabilities of the LWD assembly allowed the customer to acquire 25 formation fluid samples and a range of pressure tests in challenging, near horizontal wellbores.  Obtaining this high number and quality of formation fluid samples allowed the customer to make strategic field development decisions, saved millions of dollars in necessary retrofit costs, and substantially reduced the number of rig days.

The Baker Hughes AutoTrak X-treme? rotary steerable system has delivered excellent results across multiple regions including Latin America, Africa and U.S. Land.  The growing Marine region of Mexico experienced a drilling rate of penetration (ROP) of 200 ft/hr using the AutoTrak X-treme system as well as the Baker Hughes Quantec Force? bit, which surpassed the previous ROP record for offset wells in this field by more than 45%.  The Quantec Force bit has seen successes this quarter in Brazil and Ghana, both of which showed substantial increases in penetration rate, allowing customers to reach their targets more quickly and efficiently.

Baker Hughes continues its success with the Drill Bits product line, particularly with the Kymera? hybrid bit.  The rolling torque management with dual action cutting structures has allowed customers in Latin America, Asia Pacific, Africa, Middle East and Gulf of Mexico to experience increases in ROP and superior directional control.  The Kymera bit was deployed for the first time in China this quarter, and also had exceptional success onshore in Mauritania, allowing a 12¼-in. section to be drilled in one run, eliminating the expected extra day of rig time to run multiple bits.  In addition, we deployed a 26-in. Kymera bit was deployed for the first time in the Gulf of Mexico during the quarter and displayed excellent ROP and rig time savings.

Baker Hughes is gaining share in the Gulf of Mexico through the introduction of new technologies.  During the quarter, Baker Hughes successfully completed wireline logging operations on an ultradeepwater, high-temperature appraisal project at a total depth of 26,340 ft in the Gulf of Mexico.  The Baker Hughes RCX? Sentinel obtained fluid samples for safer, cleaner, and faster sampling.

In the Gulf of Mexico, Baker Hughes performed six individual fracpacks on a well with a single vessel, in a single trip.  The Blue Dolphin? stimulation vessel remained on location for the duration of the project without having to travel back to the dock to resupply.  Traditionally, a project of this size would have been required two vessels.  However, the capability of the Blue Dolphin allowed for the largest volume of proppant ever to be pumped into a single well in the Gulf of Mexico.

The demand for Rhino? Bifuel continues to grow.  Baker Hughes stimulated multiple wells in Canada and the U.S. this quarter with Rhino Bifuel.  Replacing up to 70% of diesel with natural gas not only reduces emissions of the pumping units, but the potential for using field gas negates the requirement for large quantities of fuel to be transported.  This transport savings can dramatically reduce an operator's environmental footprint.  Baker Hughes Rhino Bifuel pumping fleets have completed more than 400 stages to date.  With increasing demand for Rhino Bifuel, Baker Hughes plans to double its Rhino Bifuel capacity by converting additional fleets this year.

Supplemental Financial Information

Supplemental financial information can be found on the Company's website at: www.bakerhughes.com/investor in the Financial Information section under Quarterly Results.

Conference Call and Webcast

The Company has scheduled a conference call and webcast to discuss management's outlook and the results reported in today's earnings announcement.  The call will begin at 8 a.m. Eastern time, 7 a.m. Central time on Friday, July 19, 2013, the content of which is not part of this earnings release.  A slide presentation providing summary financial and statistical information that will be discussed on the conference call will also be posted to the Company's website and available for real-time viewing at www.bakerhughes.com/investor.  To access the conference call, please call the conference call operator at: 800-446-1671 in the U.S., or 847-413-3362 for international calls.  Please call in 20 minutes prior to the scheduled start time and ask for the "Baker Hughes Conference Call."  A replay of the call will be available through Friday, August 2, 2013.  The number for the replay is: 888-843-7419 in the United States, or 630-652-3042 for international calls, and the access code is:  34835209.  To access the webcast, go to our Events and Presentations page on the Company's website at: www.bakerhughes.com/investor.

Forward-Looking Statements

This news release (and oral statements made regarding the subjects of this release, including on the conference call announced herein) contain forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, (each a "forward?looking statement").  The words "anticipate," "believe," "ensure," "expect," "if," "intend," "estimate," "project," "foresee," "forecasts," "predict," "outlook," "aim," "will," "could," "should," "potential," "would," "may," "probable," "likely," and similar expressions, and the negative thereof, are intended to identify forward?looking statements.  There are many risks and uncertainties that could cause actual results to differ materially from our forward-looking statements.  These forward-looking statements are also affected by the risk factors described in the Company's Annual Report on Form 10-K for the year ended December 31, 2012, Baker Hughes' subsequent quarterly report on Form 10-Q for the quarterly period ended March 31, 2013; and those set forth from time-to-time in other filings with the Securities and Exchange Commission ("SEC").  The documents are available through the Company's website at:  www.bakerhughes.com/investor or through the SEC's Electronic Data Gathering and Analysis Retrieval System ("EDGAR") at:  www.sec.gov.  We undertake no obligation to publicly update or revise any forward?looking statement.

Our expectations regarding our business outlook and business plans; the business plans of our customers; oil and natural gas market conditions; cost and availability of resources; economic, legal and regulatory conditions and other matters are only our forecasts regarding these matters.

These forward looking statements, including forecasts, may be substantially different from actual results, which are affected by many risks including the following risk factors and the timing of any of these risk factors:

Economic conditions ? the impact of worldwide economic conditions and sovereign debt crises in Europe; the effect that declines in credit availability may have on worldwide economic growth and demand for hydrocarbons; the ability of our customers to finance their exploration and development plans; and foreign currency exchange fluctuations and changes in the capital markets in locations where we operate.

Oil and gas market conditions ? the level of petroleum industry exploration, development and production expenditures; the price of, volatility in pricing of, and the demand for crude oil and natural gas; drilling activity; drilling permits for and regulation of the shelf and the deepwater drilling; excess productive capacity; crude and product inventories; LNG supply and demand; seasonal and other adverse weather conditions that affect the demand for energy; severe weather conditions, such as tornadoes and hurricanes, that affect exploration and production activities; Organization of Petroleum Exporting Countries ("OPEC") policy and the adherence by OPEC nations to their OPEC production quotas.

Terrorism and geopolitical risks ? war, military action, terrorist activities or extended periods of international conflict, particularly involving any petroleum?producing or consuming regions; labor disruptions, civil unrest or security conditions where we operate; expropriation of assets by governmental action; cybersecurity risks and cyber incidents or attacks.

Price, market share, contract terms, and customer payments ? our ability to obtain market prices for our products and services; the ability of our competitors to capture market share; our ability to retain or increase our market share; changes in our strategic direction; the effect of industry capacity relative to demand for the markets in which we participate; our ability to negotiate acceptable terms and conditions with our customers, especially national oil companies, to successfully execute these contracts, and receive payment in accordance with the terms of our contracts with our customers; our ability to manage warranty claims and improve performance and quality; our ability to effectively manage our commercial agents.

Costs and availability of resources ? our ability to manage the costs, availability, distribution and delivery of sufficient raw materials and components (especially steel alloys, chromium, copper, carbide, lead, nickel, titanium, beryllium, barite, synthetic and natural diamonds, sand, gel, chemicals, and electronic components); our ability to manage energy-related costs; our ability to manage compliance-related costs; our ability to recruit, train and retain the skilled and diverse workforce necessary to meet our business needs and manage the associated costs; the effect of manufacturing and subcontracting performance and capacity; the availability of essential electronic components used in our products; the effect of competition, particularly our ability to introduce new technology on a forecasted schedule and at forecasted costs; potential impairment of long-lived assets; unanticipated changes in the levels of our capital expenditures; the need to replace any unanticipated losses in capital assets; labor-related actions, including strikes, slowdowns and facility occupations; our ability to maintain information security.

Litigation and changes in laws or regulatory conditions ? the potential for unexpected litigation or proceedings and our ability to obtain adequate insurance on commercially reasonable terms; the legislative, regulatory and business environment in the U.S. and other countries in which we operate; outcome of government and legal proceedings, as well as costs arising from compliance and ongoing or additional investigations in any of the countries where the Company does business; new laws, regulations and policies that could have a significant impact on the future operations and conduct of all businesses; laws, regulations or restrictions on hydraulic fracturing; any restrictions on new or ongoing offshore drilling or permit and operational delays or program reductions as a result of the regulations in the Gulf of Mexico and other areas of the world; changes in export control laws or exchange control laws; the discovery of new environmental remediation sites; changes in environmental regulations; the discharge of hazardous materials or hydrocarbons into the environment; restrictions on doing business in countries subject to sanctions; customs clearance procedures; changes in accounting standards; changes in tax laws or tax rates in the jurisdictions in which we operate; resolution of tax assessments or audits by various tax authorities; and the ability to fully utilize our tax loss carry forwards and tax credits.

Baker Hughes is a leading supplier of oilfield services, products, technology and systems to the worldwide oil and natural gas industry.  The Company's 59,000-plus employees today work in more than 80 countries helping customers find, evaluate, drill, produce, transport and process hydrocarbon resources.  For more information on Baker Hughes' century-long history, visit: www.bakerhughes.com.

Investor Contacts:Trey Clark, +1.713.439.8039, trey.clark@bakerhughes.comEric Holcomb, +1.713.439.8822, eric.s.holcomb@bakerhughes.com

Media Contact:Christine Mathers, +1.713.439.8738, christine.mathers@bakerhughes.com  

SOURCE Baker Hughes Incorporated

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