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Baker Hughes Announces Third Quarter Results

HOUSTON, Nov. 1, 2010 /PRNewswire via COMTEX News Network/ -- Baker Hughes Incorporated (NYSE: BHI) today announced net income for the third quarter 2010 of $255 million or $0.59 per share compared to net income of $55 million or $0.18 per share for the third quarter 2009 and net income of $93 million or $0.23 per share for the second quarter 2010. Third quarter 2010 results include a full three months of results from BJ Services compared to two months in the second quarter 2010.

Third quarter 2010 results include a $0.05 per share benefit relative to our guidance, resulting from a lower tax rate ($0.04 per share) and a reduction in our estimated quarterly amortization of intangibles associated with the BJ Services acquisition ($0.01 per share).

Revenue for the third quarter 2010 was $4.08 billion, up 83% compared to $2.23 billion for the third quarter 2009 and up 21% compared to $3.37 billion for the second quarter 2010.

Chad C. Deaton, Baker Hughes chairman and chief executive officer, said, "Our third quarter results in North America reflect the seasonal recovery in Canada and the strength of the US Land market. Drilling for unconventional oil and gas in key North American basins has driven demand for drilling, pressure pumping and completions products and services. In contrast, the deepwater moratorium and permitting delays on the shelf significantly reduced activity in the Gulf of Mexico, partially offsetting the increases in revenue and operating profit onshore.

"We have made good progress in integrating BJ Services and Baker Hughes. Management reporting lines are in place and sales, and operations teams are working together to successfully pull through products and services to traditional customers of both Baker Hughes and BJ Services. We are developing combined offerings for geological analysis, drilling, perforating, completions and hydraulic fracturing for our customers. Our expected cost synergies of $75 million in the first twelve months and an additional $75 million in the second twelve months remain on target.

"Our international results did not change meaningfully from the last quarter. Activity levels were as expected, except in Norway where the third quarter was impacted negatively by extended summer rig downtime. While international activity has continued to grow modestly, we have not yet seen sufficient growth in key markets to support incremental pricing.

"During the quarter we implemented the next phase of our plan to reduce costs and improve international margins. We consolidated several geomarkets in our Africa and Latin America regions and have reduced other support costs worldwide.

"Looking ahead, we expect global economic expansion to increase demand for oil and drive continued growth in our international markets. In North America we expect increases in drilling for oil and wet gas to offset weakness in dry gas activity. While we are encouraged that the Gulf of Mexico deepwater drilling moratorium has ended, the recovery of drilling in the Gulf, both in the deepwater and on the shelf, will depend on the pace of permit approval within the new regulatory framework."

Debt increased by $935 million to $3.85 billion and cash and short-term investments increased from $937 million to $1.86 billion compared to the second quarter 2010. The change in debt reflected the issuance of $1.5 billion in bonds, a portion of the proceeds of which were used to repay $511 million in commercial paper. The remainder will be used to repay the $250 million BJ Services bonds due in June 2011 and other corporate needs. Capital expenditures were $466 million, depreciation and amortization expense was $293 million and dividend payments were $64 million in the third quarter 2010.

Earnings before interest, taxes, depreciation and amortization or "EBITDA" per diluted share for third quarter 2010 was $1.64, up $0.71 or 76% compared to $0.93 for the third quarter 2009 and up $0.26 or 19% compared to $1.38 for the second quarter 2010. EBITDA is a non-GAAP measure and is calculated in Table 1 (Calculation of EBIT and EBITDA (non-GAAP measures)).

In addition to reported results, we are also providing "Supplemental Financial Information" in Table 3 for revenue and operating profit before tax (a non-GAAP measure). This information presents pro forma combined revenue and operating profit before tax for Baker Hughes and BJ Services for all periods referenced and reflects the current estimated depreciation and amortization associated with the acquisition of BJ Services.

Financial Information
Consolidated Statements of Operations

Three Months Ended
UNAUDITED ------------------
(In millions, except per
share amounts)

September 30, June 30,
------------- --------
2010 2009 2010
---- ---- ----

Revenues $4,078 $2,232 $3,374

Costs and Expenses:
Cost of revenues 3,189 1,761 2,662
Research and engineering 118 88 112
Marketing, general and
administrative 354 272 312
Acquisition-related costs 12 - 56
------------------------- --- --- ---
Total costs and expenses 3,673 2,121 3,142
------------------------ ----- ----- -----

Operating income 405 111 232
Interest expense (40) (29) (30)
Interest income 1 1 -
--------------- --- --- ---
Income before income taxes 366 83 202
Income taxes (111) (28) (109)
------------ ---- --- ----
Net income $255 $55 $93
========== ==== === ===

Basic earnings per share $0.59 $0.18 $0.23

Diluted earnings per share $0.59 $0.18 $0.23

Weighted average shares
outstanding, basic 432 310 398
Weighted average shares
outstanding, diluted 433 311 399

Depreciation and amortization
expense $293 $177 $261

Capital expenditures $466 $222 $349


Financial Information
Consolidated Statements of Operations

Nine Months Ended
UNAUDITED -----------------
(In millions, except per
share amounts)
September September
30, 30,
2010 2009
---- ----

Revenues $9,991 $7,236

Costs and Expenses:
Cost of revenues 7,763 5,518
Research and engineering 324 299
Marketing, general and
administrative 971 837
Acquisition-related costs 78 -
------------------------- --- ---
Total costs and expenses 9,136 6,654
------------------------ ----- -----

Operating income 855 582
Interest expense (95) (98)
Interest income 2 5
--------------- --- ---
Income before income taxes 762 489
Income taxes (285) (152)
------------ ---- ----
Net income $477 $337
========== ==== ====

Basic earnings per share $1.25 $1.09

Diluted earnings per share $1.25 $1.09

Weighted average shares
outstanding, basic 381 310
Weighted average shares
outstanding, diluted 382 310

Depreciation and amortization
expense $743 $532

Capital expenditures $1,005 $794


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

UNAUDITED Three Months Ended
--------- ------------------
September 30, September 30, June 30,
2010 2009 2010(2)
-------------- -------------- ---------
per per per
millions share millions share millions share
-------- ------ -------- ------ -------- ------
Net income $255 $0.59 $55 $0.18 $93 $0.23
===== ===== =====
Income taxes 111 28 109
------------ --- --- ---
Income
before
income
taxes 366 83 202
Interest
expense 40 29 30
Acquisition-
related
costs(3) 12 - 56
Earnings
before
interest
expense $418 $0.97 $112 0.36 $288 $0.72
and taxes
(EBIT) ===== ==== =====
Depreciation
and
amortization 293 177 261
expense
Earnings
before
interest
expense, $711 $1.64 $289 $0.93 $549 $1.38
taxes,
depreciation
and ==== ===== ==== ===== ==== =====
amortization
(EBITDA)
============




Nine Months Ended
-----------------
UNAUDITED
---------
September 30, September 30,
2010(2) 2009
-------------- --------------
per
millions share millions per share
-------- ------ -------- ---------
Net income $477 $1.25 $337 $1.09
----- -----
Income taxes 285 152
------------ --- ---
Income before income taxes 762 489
Interest expense 95 98
Acquisition-related costs(3) 78 -
Earnings before interest expense
and taxes (EBIT) 935 2.45 587 1.89
---- ----
Depreciation and amortization
expense 743 532
Earnings before interest
expense, taxes, depreciation
and amortization (EBITDA) $1,678 $4.39 $1,119 $3.61
============================= ====== ===== ====== =====


(1) EBIT, EBITDA, EBIT per diluted share and EBITDA per diluted share
(as defined in the calculations above) are non-GAAP measurements.
Management uses EBIT and EBITDA because it believes that such
measurements are widely accepted financial indicators used by
investors and analysts to analyze and compare companies on the basis
of operating performance.
(2) Includes results for BJ Services for May and June 2010.
(3) Costs related to the acquisition of BJ Services.

Consolidated Balance Sheets


(In millions) (UNAUDITED) (AUDITED)
============= =========== =========
September
30, December 31,
2010 2009
==== ====
ASSETS
Current Assets:
Cash and short term investments $1,856 $1,595
Accounts receivable, net 3,763 2,331
Inventories, net 2,509 1,836
Deferred income taxes 285 268
Other current assets 297 195
Total current assets 8,710 6,225
-------------------- ----- -----

Property, plant and equipment, net 6,108 3,161
Goodwill 5,714 1,418
Intangible assets, net 1,512 195
Other assets 418 440
Total assets $22,462 $11,439
============ ======= =======

LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Accounts payable $1,371 $821
Short-term borrowings and current
portion of 291 15
long-term debt
Accrued employee compensation 849 448
Income taxes payable 25 95
Other accrued liabilities 500 234
Total current liabilities 3,036 1,613
------------------------- ----- -----

Long-term debt 3,555 1,785
Deferred income taxes and other tax
liabilities 1,387 309
Liabilities for pensions and other
postretirement benefits 525 379
Other liabilities 202 69

Stockholders' Equity:
Common stock 431 312
Capital in excess of par value 6,949 874
Retained earnings 6,814 6,512
Accumulated other comprehensive loss (437) (414)
Total stockholders' equity 13,757 7,284
-------------------------- ------ -----
Total liabilities and stockholders'
equity $22,462 $11,439
=================================== ======= =======



Table 2: Segment Revenue, Profit Before Tax, and Profit Before Tax
Margin,(1,2)

(In millions) Three Months Ended
------------------
September September
30, 30, June 30,
---------- ---------- --------
2010 2009 2010
---- ---- ----
Segment Revenue
North America $2,006 $714 $1,486
Latin America 431 257 384
Europe /Africa /Russia
Caspian 757 626 736
Middle East /Asia Pacific 606 463 545
Industrial and Other 278 172 223
-------------------- --- --- ---
Oilfield Operations 4,078 $2,232 3,374
=================== ===== ====== =====


Profit Before Tax
North America $340 $28 $204
Latin America 9 16 13
Europe /Africa /Russia
Caspian 47 79 69
Middle East /Asia Pacific 39 50 40
Industrial and Other 36 14 18
-------------------- --- --- ---
Oilfield Operations 471 187 344
------------------- --- --- ---

Corporate and Other Profit
Before Tax
Acquisition-related
costs(3) $(12) $- $(56)
Interest expense (40) (29) (30)
Interest income 1 1 -
Corporate and other (54) (76) (56)
------------------- --- --- ---
Corporate, net interest
and other (105) (104) (142)
----------------------- ---- ---- ----
Total Profit Before Tax $366 $83 $202
======================= ==== === ====

Profit Before Tax
Margin(2)
North America 17% 4% 14%
Latin America 2% 6% 3%
Europe /Africa /Russia
Caspian 6% 13% 9%
Middle East /Asia Pacific 6% 11% 7%
Industrial and Other 13% 8% 8%
-------------------- --- --- ---
Oilfield Operations 12% 8% 10%
=================== === === ===



(1) Before April 2010 we reported results for two segments - Drilling
and Evaluation and Completion and Production. In May 2009, we
announced a new organization for Baker Hughes and began a transition
period in which both product line and geographic information were
used to allocate resources and assess performance. That transition
was completed at the beginning of the second quarter 2010 and we are
now disclosing results for five segments: North America (Canada, US
and Trinidad), Latin America (including Mexico), Europe / Africa /
Russia Caspian (excluding Egypt), Middle East / Asia Pacific
(including Egypt), and Industrial and Other (downstream chemicals,
process and pipeline equipment, and reservoir technology and
consulting). The second quarter 2010 includes results for BJ
Services for the months of May and June 2010. Information on Baker
Hughes results by these new segments can be found on our website at
www.bakerhughes.com/investor in the Financial Information section.

(2) 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.

(3) Costs related to the acquisition of BJ Services.


Table 3: Supplemental Financial Information (Pro Forma Combined
Basis)(1)

The following table contains non-GAAP measures of segment revenue,
operating profit before tax(2), and operating profit before tax
margin(3). Management uses this information to perform meaningful
comparisons between quarters and believes that this information may
be useful to investors. It is based on revenue and operating profit
before tax: (1) previously reported by Baker Hughes in all periods;
(2) previously reported by BJ Services for the quarter ended
September 30, 2009; and (3) estimated by BJ Services for the month
of April 2010. Revenue and operating profit before tax have been
reclassified into Baker Hughes' new segments. Operating profit
before tax for all periods includes pro forma charges of $33 million
per quarter for depreciation and amortization of tangible and
intangible assets associated with the acquisition of BJ Services and
a credit to corporate interest expense of $3 million, for a net of
$30 million. The historical allocation to segments of depreciation
and amortization of tangible and intangible assets associated with
the acquisition of BJ Services is the same as the actual allocation
of these charges in May and June 2010. No adjustments have been
made for cost or revenue synergies or any other integration related
items that may have affected these quarters. Operating profit before
tax for Baker Hughes and BJ Services also excludes expenses for
reorganization, severance, impairment, and increases to allowance
for doubtful accounts identified by each of the companies in their
respective earnings news releases for the quarter ended September
30, 2009. Supplemental financial information for the first quarter
2008 through the third quarter 2010 can be found on our website at
www.bakerhughes.com/investor in the Financial Information section.


(In millions) Three Months Ended
------------------
September 30, September 30, June 30,
------------- ------------- --------
2010 2009(4) 2010
---- ------ ----
Segment Revenue
North America $2,006 $1,170 $1,728
Latin America 431 400 424
Europe /Africa /Russia
Caspian 757 716 767
Middle East /Asia Pacific 606 572 579
Industrial and Other 278 252 247
-------------------- --- --- ---
Oilfield Operations 4,078 3,110 3,745
=================== ===== ===== =====


Operating Profit Before
Tax(2)
North America(2) $340 $(16) $223
Latin America(2) 9 33 9
Europe /Africa /Russia
Caspian(2) 47 86 69
Middle East /Asia
Pacific(2) 39 75 41
Industrial and Other 36 28 20
-------------------- --- --- ---
Oilfield Operations 471 206 362
=================== === === ===

Operating Profit Before
Tax Margin(3)
North America 17% (1)% 13%
Latin America 2% 8% 2%
Europe /Africa /Russia
Caspian 6% 12% 9%
Middle East /Asia Pacific 6% 13% 7%
Industrial and Other 13% 11% 8%
-------------------- --- --- ---
Oilfield Operations 12% 7% 10%
=================== === === ===



(1) This supplemental financial information is provided for
illustrative purposes and is not intended to represent or be
indicative of the consolidated results of operations or financial
position of Baker Hughes had the acquisition been completed as of
the dates presented and should not be taken as representative of
future results of operations or financial position of the combined
company.
(2) Operating profit before tax is a non-GAAP measure defined as
profit before tax ("income before income taxes") less certain
identified costs. Management uses operating profit before tax
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 and that this measurement may be used
by investors to make informed investment decisions.
(3) Operating profit before tax margin is a non-GAAP measure defined
as operating profit before tax divided by revenue. Management uses
the operating 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.
(4) Operating profit before tax in the third quarter 2009 excludes
these identified costs: (1) charges Baker Hughes disclosed
associated with reorganization, severance and acquisition costs
(associated with the acquisition of BJ Services) were $33 million,
and charges associated with allowances for doubtful accounts were $5
million in the third quarter 2009, totaling $38 million, and were
recognized in the following segments: North America -$15 million;
Latin America -$3 million; EARC -$3 million; and MEAP -$8 million
and $9 million at Corporate; (2) BJ Services charges associated with
reorganization, severance and merger costs were $11 million, and
were recognized in the following segments: North America -$1
million; Latin America -$2 million; and MEAP -$3 million and $5
million at Corporate.

Operational Highlights

North America

During the third quarter, we opened a repair and maintenance facility in Westmoreland County, Pennsylvania to service the Marcellus Shale.

Also in North America, we were chosen by a large independent oil and gas company as the prime service provider for equipment and services to drill and complete a horizontal unconventional gas well with a 10-stage open-hole fracturing system and an integrated fiber optic monitoring system. The successful installation was accomplished utilizing the AutoTrak(TM) rotary steerable drilling system, drill bits, Frac-Point(TM) open hole fracturing system, InSite(TM) DTS fiber optic monitoring system and pumping services for cementing and fracturing.

With the recent launch of the Nautilus Ultra formation evaluation suite, we have enhanced our position a premium provider of extreme HPHT wireline services. This technology allows our clients to reliably gather critical petrophysical data in temperatures up to 500 degrees Fahrenheit and up to 30,000 psi.

Latin America

In the Andean geomarket, we won a $137 million, eight-year contract extension from Repsol for the exclusive supply and maintenance of ESP systems in Ecuador's Block 16 and Tivacuna production areas.

Also in the Andean geomarket, we were awarded a two-year contract by Rio Napo for a full-service well construction solution that includes drilling & evaluation systems, fluids and cementing/pumping services.

In the Brazil geomarket we have successfully deployed a 12 1/4 inch Kymera drill bit for the first time in a North East Brazil onshore application. The bit was able to drill 20% further and 90% faster than standard tricone bits.

Europe / Africa / Russia Caspian

In Norway, we secured a multimillion dollar integrated project for the Borgland Dolphin Consortium (BDC) to provide service integration and planning, including directional drilling, measurement-while-drilling, logging-while-drilling, mud logging, fluids, wireline logging and coring services.

We strengthened our position across the North Sea in both the UK and Norway through an award to provide well placement, wireline logging, drilling fluids, liners, and completion services for up to 3 years on Valhall Flanks which will be drilled by Maersk Reacher.

In the Sub-Saharan Africa geomarket, our local joint venture won a 10 year offshore production chemicals contract with a super major in Angola.

In the North Africa geomarket, we have been awarded a tender for directional drilling, logging-while-drilling, coring, liner hangers, bits and cementing by Occidental Libya Oil & Gas BV. The two-year, 22-well program starts in the first quarter 2011.

Also in the North Africa geomarket, we secured a directional drilling, logging-while-drilling, fluids surface logging services and cementing chemicals, and drill bits contract on a new deepwater semi-submersible rig by an independent operator offshore Mauritania.

In the Russia Caspian region, we have successfully performed our first rotary steerable job in Western Siberia utilizing the AutoTrak, OnTrak and LithoTrak systems for an independent gas producer. Successful drilling operations led to an award for six additional multi-lateral completion systems.

Middle East / Asia Pacific

In the Saudi Arabia/Bahrain geomarket we are installing FracPoint multi-zone completion equipment in five wells with tight gas reservoirs in Saudi Arabia.

Across the Middle East region we are setting drilling records in hard, abrasive formations by combining Quantec Force bits with Xtreme motors. Our Rib Steer Motor for Coil Tubing operation is drilling longer-reach laterals in significantly reduced time.

In the Australasia geomarket we won a three-year, multi-million dollar contract from Woodside Petroleum to provide casing and tubing running services in Australia.

In the Southeast Asia geomarket, we secured a major geothermal services contract with EDC, a leading geothermal company in the Philippines. We will be providing cementing, directional drilling and drilling fluids services on five rigs as part of a two-year contract with a 50-well work scope.

Also in the Southeast Asia geomarket, BHP Billiton and PETRONAS recently awarded us a four-year contract for directional drilling, logging-while-drilling, electric wireline and coring services offshore Malaysia.

In the Australasia geomarket, we recently completed a complex, three-dimensional horizontal well in 2,700 ft. deep water offshore Australia for BHP Billiton. The AutoTrak system was deployed in all three hole sections to place the wellbore in the reservoir with pin point accuracy.

In the Indonesia geomarket we completed a two-MST system gravel pack completion in a single well isolating two differentially pressured zones. This completion builds on the success of our MST (Multi-zone single-trip completion system) which has had over 35 successful runs to date with documented savings of 70% of rig time -- from approximately 20 days to 3-1/2 days.

Industrial and Other

Baker Hughes and Intertek Group plc have formed an alliance to provide cargo treatment additive services to the global petroleum industry. The alliance offers a fast and effective spectrum of services for fuel and bulk cargos to meet trade specifications with the extensive additive treatment services, PREPARED TO RESPOND (P2R), from Baker Hughes and Intertek's cargo inspection, testing and technical services.

Conference Call

The company has scheduled a conference call to discuss the results reported in today's earnings announcement. The call will begin at 8:30 a.m. Eastern time, 7:30 a.m. Central time, on Monday November 1, 2010, 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. To access the call, which is open to the public, please contact the conference call operator at (800) 374-2469, or (706) 634-7270 for international callers, 20 minutes prior to the scheduled start time, and ask for the "Baker Hughes Conference Call." A replay will be available through Monday, November 15, 2010. The number for the replay is (800) 642-1687, or (706) 645-9291 for international callers, and the access code is 14716071. The conference call will be webcast simultaneously at http://investor.shareholder.com/bhi/events.cfm on a listen-only basis. The call and replay will also be available on our 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," "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, 2009; quarterly reports on form 10-Q for the quarters ended March 31, 2010 and June 30, 2010 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 http://www.bakerhughes.com/investor or through the SEC's Electronic Data Gathering and Analysis Retrieval System (EDGAR) at http://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; the integration of BJ Services, including its synergies, financial results and operations; 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:

Baker Hughes - BJ Services acquisition - preliminary estimates of acquisition accounting may change; the inability to achieve the expected benefits of the acquisition, including financial and operating results; the risk that the cost savings and any other synergies from the transaction may not be realized or take longer to realize than expected; the ability to successfully integrate the businesses; and with respect to the historical financial information for BJ Services disclosed or utilized in this news release the following: the estimates, pro forma calculations and quarterly results have not been audited and actual results may differ materially, no assurance can be given that these results were realized or can be considered predictive of actual or future results, and that we do not intend to update or otherwise revise these estimates.

Economic conditions - the impact of worldwide economic conditions; 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; foreign currency exchange fluctuations and changes in the capital markets in locations where we operate; the condition of financial institutions and the debt, capital and equity markets in general, any impact on our ability to borrow to fund short-term cash requirements and retire long-term debt upon maturity as well as any impact on our customers' spending and ability to pay amounts owed to us; our ability to estimate the size of and changes in the worldwide oil and natural gas industry.

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; the impact of recovery from the now lifted US Gulf of Mexico drilling moratorium and changes in the regulation of offshore drilling in the US Gulf of Mexico as well as higher operating costs; excess productive capacity; crude and product inventories; LNG imports; seasonal and other adverse weather conditions that affect the demand for energy; severe weather conditions, such as 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 major petroleum-producing or consuming regions; labor disruptions, civil unrest or security conditions where we operate; expropriation of assets by governmental action.

Price, market share, contract terms, and customer payments - our ability to obtain market prices for our products and services; the effect of the level and sources of our profitability on our tax rate; 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, 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 and availability of sufficient raw materials and components (especially steel alloys, chromium, copper, carbide, lead, nickel, titanium, beryllium, barite, synthetic and natural diamonds, sand, 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, including forecasted costs to meet our revenue goals; 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; the accuracy of our estimates regarding our capital spending requirements; 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.

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 US 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; restrictions on hydraulic fracturing; any restrictions on new or ongoing offshore drilling; permit and operational delays or program reductions as a result of the new regulations and recovery from the drilling moratorium in the Gulf of Mexico; changes in export control laws or exchange control laws; restrictions on doing business in countries subject to sanctions; customs clearance procedures; changes in laws in countries identified by management for immediate focus; 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.

Environmental matters - unexpected, adverse outcomes or material increases in liability with respect to environmental remediation sites where we have been named as a potentially responsible party; the discovery of new environmental remediation sites; changes in environmental regulations; the discharge of hazardous materials or hydrocarbons into the environment.

Baker Hughes provides reservoir consulting, drilling, pressure pumping, formation evaluation, completion and production products and services to the worldwide oil and gas industry.


SOURCE Baker Hughes Incorporated

Copyright (C) 2010 PR Newswire. All rights reserved

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