10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10–K

(Mark One)

x ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 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 001-34658

THE BABCOCK & WILCOX COMPANY

(Exact name of registrant as specified in its charter)

DELAWARE	80-0558025
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)
THE HARRIS BUILDING 13024 BALLANTYNE CORPORATE PLACE SUITE 700 CHARLOTTE, NORTH CAROLINA	28277
(Address of Principal Executive Offices)	(Zip Code)

Registrant’s Telephone Number, Including Area Code: (704) 625-4900

Securities Registered Pursuant to Section 12(b) of the Act:

Title of each class	Name of each Exchange on which registered
Common Stock, $0.01 par value	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

    Yes  þ    No  ¨

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.     Yes  ¨    No  þ

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   þ    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   þ    No  ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.   þ

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 definition of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer	þ	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  þ

The aggregate market value of the registrant’s common stock held by nonaffiliates of the registrant on the last business day of the registrant’s most recently completed second fiscal quarter (based on the closing sales price on the New York Stock Exchange on June 29, 2012) was approximately $2.9 billion.

The number of shares of the registrant’s common stock outstanding at January 31, 2013 was 114,344,972.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant’s proxy statement for the 2013 Annual Meeting of Stockholders are incorporated by reference into Part III of this Form 10-K.

THE BABCOCK & WILCOX COMPANY

INDEX—FORM 10-K

		PAGE
	PART I
Item 1.	Business
	General		1
	Business Segments		1
	Acquisitions and Investments		4
	Contracts		5
	Backlog		6
	Competition		7
	Joint Ventures		7
	Foreign Operations		10
	Customers		10
	Raw Materials and Suppliers		11
	Employees		11
	Patents and Licenses		11
	Research and Development Activities		11
	Hazard Risks and Insurance		12
	Governmental Regulations and Environmental Matters		14
	Cautionary Statement Concerning Forward-Looking Statements		15
	Available Information		17
Item 1A.	Risk Factors		18
Item 1B.	Unresolved Staff Comments		34
Item 2.	Properties		34
Item 3.	Legal Proceedings		34
Item 4.	Mine Safety Disclosures		34
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities		35
Item 6.	Selected Financial Data		38
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		39
	General		39
	Critical Accounting Policies and Estimates		42
	Year Ended December 31, 2012 Compared to Year Ended December 31, 2011		46
	Year Ended December 31, 2011 Compared to Year Ended December 31, 2010		49
	Effects of Inflation and Changing Prices		51
	Liquidity and Capital Resources		52
Item 7A.	Quantitative and Qualitative Disclosures about Market Risk		55
Item 8.	Financial Statements and Supplementary Data
	Report of Independent Registered Public Accounting Firm		57
	Consolidated Balance Sheets – December 31, 2012 and December 31, 2011		58
	Consolidated and Combined Statements of Income for the Years Ended December 31, 2012, 2011 and 2010		60

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	Consolidated and Combined Statements of Comprehensive Income for the Years Ended December  31, 2012, 2011 and 2010	61
	Consolidated and Combined Statement of Stockholders’ Equity for the Years Ended December  31, 2012, 2011 and 2010	62
	Consolidated and Combined Statements of Cash Flows for the Years Ended December  31, 2012, 2011 and 2010	63
	Notes to Consolidated and Combined Financial Statements	64
Item 9.	Changes In and Disagreements With Accountants on Accounting and Financial Disclosure	114
Item 9A.	Controls and Procedures
	Disclosure Controls and Procedures	115
	Management’s Report on Internal Control Over Financial Reporting	115
	Changes in Internal Control Over Financial Reporting	115
	Report of Independent Registered Public Accounting Firm	116
Item 9B.	Other Information	116
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	117
Item 11.	Executive Compensation	117
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	117
Item 13.	Certain Relationships and Related Transactions, and Director Independence	117
Item 14.	Principal Accountant Fees and Services	117
PART IV
Item 15.	Exhibits and Financial Statement Schedules	118
Signatures		123

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Statements we make in this Annual Report on Form 10-K, which express a belief, expectation or intention, as well as those that are not historical fact, are forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements are subject to various risks, uncertainties and assumptions, including those to which we refer under the headings “Cautionary Statement Concerning Forward-Looking Statements” and “Risk Factors” in Items 1 and 1A of Part I of this report. In this annual report on Form 10-K, unless the context otherwise indicates, “we,” “us” and “our” mean The Babcock & Wilcox Company (“B&W”) and its consolidated subsidiaries.

PART I

Item 1. BUSINESS

General

B&W is a leading technology innovator in power generation systems, a specialty constructor of nuclear components and a premier service provider in its segments, with an operating history of more than 140 years. We provide a variety of products and services to customers in the power and other steam-using industries, including electric utilities and other power generators, industrial customers in various other industries, and the United States Government. While we provide a wide range of products and services, our business segments are heavily focused on major projects. At any given time, a relatively small number of projects can represent a significant part of our operations.

We are a successor to a business founded in 1867, which was acquired by McDermott International, Inc. (“MII”) in 1978. On December 7, 2009, MII announced its plans to spin-off the businesses that comprised its then power generation systems and government operations segments into a separate independent public company. To effect the spin-off, MII incorporated B&W in Delaware in March 2010 as a direct wholly owned subsidiary of MII and in June 2010 implemented a reorganization that combined all of the entities that made up those businesses under our company.

On July 2, 2010, MII’s Board of Directors approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of MII common stock. The distribution of B&W common stock was made on July 30, 2010, and consisted of one share of B&W common stock for every two shares of MII common stock to holders of MII common stock as of 5:00 p.m. New York City time on the record date, July 9, 2010. Cash was paid in lieu of any fractional shares of B&W common stock. B&W became a separate publicly traded company, and MII did not retain any ownership interest in us. B&W’s common stock is listed on the New York Stock Exchange under the trading symbol BWC.

Business Segments

We operate in four business segments: Power Generation, Nuclear Operations, Technical Services and Nuclear Energy. For financial information about our segments, see Note 17 to our consolidated and combined financial statements included in this report.

Power Generation

Through this segment, we supply boilers fired with fossil fuels, such as coal, oil and natural gas, or renewable fuels such as biomass, municipal solid waste and concentrated solar energy. In addition, we supply environmental equipment and components and related services to customers in different regions around the world. We design, engineer, manufacture, supply, construct and service large utility and industrial power generation systems, including boilers used to generate steam in electric power plants, pulp and paper making, chemical and process applications and other industrial uses.

This segment specializes in engineering, manufacturing, procurement, and erection of equipment used in the power generation industry and various other industries, and the provision of related services, including:

• engineered-to-order services, products and systems for energy conversion worldwide and related auxiliary equipment, such as burners, pulverizers, soot blowers and ash handling systems;

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• heavy-pressure equipment for energy conversion, such as boilers fueled by coal, oil, bitumen, natural gas, municipal solid waste, biomass and other fuels;

• environmental control systems, including both wet and dry scrubbers for flue gas desulfurization, modules for selective catalytic reduction of the oxides of nitrogen, equipment to capture particulate matter, such as fabric filter baghouses and wet and dry electrostatic precipitators, and similar devices; and

• power plant equipment and related heavy mechanical erection services.

We support primarily fossil operating plants with a wide variety of additional services, including the installation of new systems and replacement parts, engineering services, construction, inspection, maintenance and field technical services, such as condition assessments and inventory services. We offer a wide range of construction services through a wholly owned subsidiary including erection of utility and industrial boiler plants and installations of cogeneration facilities and pollution control equipment, such as selective catalytic reduction systems and flue gas desulfurization scrubbers.

We also provide power through cogeneration, refuse-fueled power plants and other independent power-producing facilities. In this market, we own and operate proprietary facilities, supply equipment and serve as contractors for engineer-procure-construct services and operations and maintenance.

Our Power Generation segment’s overall activity depends mainly on the capital expenditures of electric power generating companies and other steam-using industries. Several factors influence these expenditures, including:

• prices for electricity, along with the cost of production and distribution;

• prices for coal and natural gas and other sources used to produce electricity;

• demand for electricity, paper and other end products of steam-generating facilities;

• availability of other sources of electricity, paper or other end products;

• requirements for environmental improvements;

• impact of potential regional, state, national and/or global requirements to significantly limit or reduce greenhouse gas emissions in the future;

• level of capacity utilization at operating power plants, paper mills and other steam-using facilities;

• requirements for maintenance and upkeep at operating power plants and paper mills to comply with environmental regulations and combat the accumulated effects of wear and tear;

• ability of electric generating companies and other steam users to raise capital; and

• relative prices of fuels used in boilers, compared to prices for fuels used in gas turbines and other alternative forms of generation.

Our Power Generation segment’s products and services are capital intensive. As such, customer demand is heavily affected by the variations in our customers’ business cycles and by the overall economies of the countries in which they operate.

For further details regarding our Power Generation segment’s facilities, see Item 2, “Properties.”

Nuclear Operations

Through this segment, we engineer, design and manufacture precision naval nuclear components and reactors for the U.S. Department of Energy (“DOE”)/National Nuclear Security Administration’s (“NNSA”) Naval Nuclear Propulsion Program.

Our Nuclear Operations segment specializes in the design and manufacture of close-tolerance and high-quality equipment for nuclear applications. In addition, we are a leading manufacturer of critical nuclear components, fuels and assemblies for government and limited commercial uses. We have supplied nuclear components for DOE programs since the 1950s, and we are the largest domestic supplier of research reactor fuel elements for colleges, universities and national laboratories. We also convert or downblend high-enriched uranium into low-enriched fuel for use in commercial reactors to generate electricity. In addition, we have over 100 years of experience in supplying components for defense applications.

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We work closely with the DOE-supported nuclear non-proliferation program. Currently, this program is assisting in the development of a high-density, low-enriched uranium fuel required for high-enriched uranium test reactor conversions. We have also been a leader in the receipt, storage, characterization, dissolution, recovery and purification of a variety of uranium-bearing materials. All phases of uranium downblending and uranium recovery are provided at our Lynchburg, Virginia and Erwin, Tennessee sites.

Our Nuclear Operations segment’s manufacturing operations are generally capital intensive. The demand for nuclear components by the U.S. Government determines a substantial portion of this segment’s backlog. We expect that orders for nuclear components will continue to be a significant part of backlog for the foreseeable future; however, such orders are subject to defense department budget constraints.

For further details regarding our Nuclear Operations segment’s facilities, see Item 2, “Properties.”

Technical Services

Through this segment, we provide various services to the U.S. Government, including uranium processing, environmental site restoration services and management and operating services for various U.S. Government-owned facilities. These services are provided to the DOE, including the NNSA, the Office of Nuclear Energy, the Office of Science, the Department of Defense and the Office of Environmental Management.

This segment’s principal operations include:

• managing and operating nuclear production facilities;

• managing and operating environmental management sites;

• managing spent nuclear fuel and transuranic waste for the DOE; and

• providing critical skills and resources for DOE sites.

We manage and operate complex, high-consequence nuclear and national security operations for the DOE and the NNSA, primarily through our joint ventures, as further discussed under the caption “Joint Ventures” below.

Our Technical Services segment’s overall activity primarily depends on authorized spending levels of the DOE, NNSA, the Office of Nuclear Energy, the Office of Science, the Department of Defense and the Office of Environmental Management.

Nuclear Energy

Through this segment, we supply commercial nuclear steam generators and components to nuclear utility customers. In addition, this segment offers a full spectrum of services for steam generators and balance of plant equipment, as well as nondestructive examination and tooling/repair solutions for other plant systems and components. Our Nuclear Energy segment fabricates pressure vessels, reactors, steam generators, heat exchangers and other auxiliary equipment. This segment also provides specialized engineering and maintenance services and power plant construction.

To further serve the nuclear power industry, through Generation mPower LLC, a joint venture with Bechtel Power, we are actively developing the B&W mPower™ reactor, a small modular reactor design with the flexibility to provide between 180 MW to greater than 1,000 MW of electrical power generation (in increments of 180 MW) and the capacity to operate for a four year operating cycle without refueling. As part of this initiative, the Nuclear Energy segment applied for, and has been selected to receive, funding from the DOE under its Small Modular Reactor Licensing Technical Support Program (“Funding Program”), which provides financial assistance for small modular reactor designs demonstrating, among other things, the ability to support a commercial operating date for a small modular reactor plant by 2022. The Nuclear Energy segment plans to meet all of the requirements of the Funding Program, including the requirement to deploy this technology by 2022. We believe the B&W mPower™ reactor will reduce risks associated with deploying nuclear power and become a flexible, cost-effective solution for meeting increasing electricity needs.

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This segment specializes in performing full scope, prototype design work coupled with manufacturing integration. The design, engineering and other capabilities of this segment include:

• steam separation equipment design and development;

• thermal-hydraulic design of reactor plant components;

• structural component design for precision manufacturing;

• materials expertise in high-strength, low-alloy steels, and nickel-based materials;

• material procurement of tubing, forgings and weld wire; and

• metallographic and chemical analysis.

Our Nuclear Energy segment’s overall activity primarily depends on our continued successful efforts in developing our B&W mPower™ reactor technology and on the capital expenditures and maintenance spending of nuclear utilities.

Acquisitions and Investments

We continue to evaluate growth opportunities achievable through acquisition or consolidation, in addition to pursuing organic growth strategies.

Acquisitions

Anlagenbau und Fördertechnik Arthur Loibl GmbH. In November 2011, a subsidiary within our Power Generation segment acquired Anlagenbau und Fördertechnik Arthur Loibl GmbH (“Loibl”), a German-based manufacturer of material handling equipment for $24.2 million. Loibl expands the products, services and global reach of this segment’s Allen-Sherman-Hoff business, which is one of the world’s leading suppliers of ash handling solutions for the power generation and other industries.

GE Energy Businesses. In April 2010, we acquired the assets of the electrostatic precipitator aftermarket and emissions monitoring business units of GE Energy, a division of General Electric Company, for approximately $21.4 million. This acquisition includes GE Energy’s electrostatic precipitator replacement parts and mechanical components product lines, performance-enhancing hardware, controls and software, remote diagnostics equipment and emissions monitoring products and services. These products and services are used by a wide variety of power generation and industrial customers to monitor and control particulates and other emissions from power plants, factories and other facilities.

Gőtaverken Miljő AB. In January 2010, a subsidiary within our Power Generation segment, Babcock & Wilcox Volund A/S (“B&W Volund”), acquired the net assets of Gőtaverken Miljő AB, a flue gas cleaning and energy recovery company based in Gothenburg, Sweden. This business complements our B&W Volund subsidiary, a leading supplier of equipment and technologies designed to convert municipal solid waste and biomass into thermal energy.

Investments

USEC Investment. In May 2010, our subsidiary Babcock & Wilcox Investment Company (“BWICO”) entered into an agreement with Toshiba Corporation (“Toshiba”), which was subsequently assigned to one of its subsidiaries, and USEC Inc. (“USEC”) to make a strategic investment in USEC totaling $200 million payable over three phases. In September 2010, following the satisfaction of certain conditions, including the availability to USEC’s American Centrifuge program of at least $2 billion in uncommitted funds under the DOE’s loan guarantee program for front-end nuclear fuel facilities and the establishment of a joint venture between us and USEC for supply by the joint venture of centrifuges and related equipment for the American Centrifuge program, we made a $37.5 million investment in USEC as part of a definitive agreement for us to make a total $100 million strategic investment in USEC.

In connection with our investment, we received 37,500 shares of USEC Series B-1 12.75% Convertible Preferred Stock and Warrants to purchase 3,125,000 shares of USEC Class B Common Stock at an exercise price of $7.50 per share, which are exercisable between January 1, 2015 and December 31, 2016, and a seat on USEC’s board of directors.

See Note 2 to our consolidated and combined financial statements included in this report for additional information concerning our investment in USEC.

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Contracts

We execute our contracts through a variety of methods, including fixed-price, cost-plus, target price cost incentive, cost-reimbursable or some combination of these methods. Contracts are usually awarded through a competitive bid process. Factors that customers may consider include price, plant or equipment availability, technical capabilities of equipment and personnel, efficiency, safety record and reputation.

Fixed-price contracts are for a fixed amount to cover all costs and any profit element for a defined scope of work. Fixed-price contracts entail more risk to us because they require us to predetermine both the quantities of work to be performed and the costs associated with executing the work. For further specification see “Risk Factors – We are subject to risks associated with contractual pricing in our industries, including the risk that, if our actual costs exceed the costs we estimate on our fixed-price contracts, our profitability will decline, and we may suffer losses” in Item 1A of this report.

We have contracts that extend beyond one year. Most of our long-term contracts have provisions for progress payments. We attempt to cover anticipated increases in labor, material and service costs of our long-term contracts either through an estimate of such changes, which is reflected in the original price, or through risk-sharing mechanisms, such as escalation or price adjustments for items such as labor and commodity prices.

We generally recognize our contract revenues and related costs on a percentage-of-completion basis. Accordingly, we review contract price and cost estimates periodically as the work progresses and reflect adjustments in profit proportionate to the percentage of completion in the period when we revise those estimates. To the extent that these adjustments result in a reduction or an elimination of previously reported profits with respect to a project, we would recognize a charge against current earnings, which could be material. For the majority of parts orders and certain aftermarket services activities, we recognize revenues as goods are delivered and work is performed.

Our contracts with the U.S. Government are subject to annual funding determinations. In addition, contracts between the U.S. Government and its prime contractors usually contain standard provisions for termination at the convenience of the U.S. Government or the prime contractor. As a U.S. Government contractor, we are subject to federal regulations under which our right to receive future awards of new federal contracts would be unilaterally suspended or barred if we were convicted of a crime or indicted based on allegations of a violation of specific federal statutes. In addition, some of our contracts with the U.S. Government require us to provide advance notice in connection with any contemplated sale or shut down of the relevant facility. In each of those situations, the U.S. Government has an exclusive right to negotiate a mutually acceptable purchase of the facility. The contracts for the management and operation of U.S. Government facilities are awarded through a complex and protracted procurement process. These contracts are generally structured as five-year contracts with five-year renewal options, which are exercisable by the customer, or include provisions whereby the contract durations can be extended as a result of the achievement of certain performance metrics. These are cost-reimbursement contracts with a U.S. Government credit line with some corporate-funded working capital required. However, many new contracts currently in the bidding process and recently awarded have a different structure. While such contracts remain cost-reimbursement contracts, the contractor is required to supply working capital and be reimbursed by the U.S. Government through regular invoicing. These contracts include a fee primarily based on performance, which is evaluated annually.

Our arrangements with customers frequently require us to provide letters of credit, bid and performance bonds or guarantees to secure bids or performance under contracts. While these letters of credit, bonds and guarantees may involve significant dollar amounts, historically, there have been no material payments to our customers under these arrangements.

In the event of a contract deferral or cancellation, we generally would be entitled to recover costs incurred, settlement expenses and profit on work completed prior to deferral or termination. Significant or numerous cancellations could adversely affect our business, financial condition, results of operations and cash flows.

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Backlog

Backlog represents the dollar amount of revenue we expect to recognize in the future from contracts awarded and in progress. Not all of our expected revenue from a contract award is recorded in backlog for a variety of reasons, including that some projects are awarded and completed within the same fiscal quarter.

Backlog is not a measure defined by generally accepted accounting principles, and our methodology for determining backlog may not be comparable to the methodology used by other companies in determining their backlog amounts. Backlog may not be indicative of future operating results, and projects in our backlog may be cancelled, modified or otherwise altered by customers.

We generally include expected revenue of contracts in our backlog when we receive written confirmation from our customers.

Our backlog at December 31, 2012 and 2011 was as follows:

	December 31,				December 31,
	2012				2011
	(Dollars in millions)
Power Generation	$	2,483	43	%	$	1,947	37	%
Nuclear Operations		2,984	52	%		2,995	56	%
Technical Services		4	0	%		14	0	%
Nuclear Energy		278	5	%		383	7	%
Total Backlog	$	5,749	100	%	$	5,339	100	%

Of the December 31, 2012 backlog, we expect to recognize revenues as follows:

	2013		2014		Thereafter
	(In approximate millions)
Power Generation	$	1,200	$	300	$	983
Nuclear Operations		1,100		740		1,144
Technical Services		4		—		—
Nuclear Energy		180		40		58
Total Backlog	$	2,484	$	1,080	$	2,185

As of December 31, 2012, our backlog with the U.S. Government, primarily attributable to our Nuclear Operations segment, was approximately $3.0 billion (of which $180.6 million has been awarded but not yet funded), or approximately 52% of our total consolidated backlog. We do not include the value of our unconsolidated joint venture contracts in backlog, which may be material. These unconsolidated joint ventures are included in our Power Generation, Technical Services and Nuclear Energy segments. See Note 3 to our consolidated and combined financial statements included in this report for financial information on our equity method investments.

During the year ended December 31, 2012, the U.S. Government awarded us new orders of approximately $1,153.1 million, $1,078.7 million of which pertains to our Nuclear Operations segment. Major new awards from the U.S. Government are typically received during the fourth quarter of each year, following congressional approval of the budget for the government’s next fiscal year, which starts October 1.

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Competition

The competitive environments in which each segment operates are described below.

Power Generation. With more than 140 years of experience, we provide advanced steam generating equipment, emissions control equipment and services. Having supplied worldwide capacity of more than 300,000 megawatts and some of the world’s largest and most efficient steam generating systems, we have a competitive advantage in our experience and technical capability to reliably convert a wide range of fuels to steam. Our strong, installed base in North America also yields competitive advantages in after-market services, although this segment of the market is highly competitive and price sensitive. Through this segment, we compete with a number of domestic and foreign-based companies specializing in steam generating systems technology, equipment and services, including Alstom S.A., Doosan Babcock, Babcock Power, Inc., Foster Wheeler AG., and Hitachi, Ltd.; a variety of engineering and construction companies with respect to the installation of steam-generating systems; a number of additional companies in the markets for environmental control equipment and related specialized industrial equipment and in the independent power-producing business; and other suppliers of replacement parts, repair and alteration services and other services required to retrofit and maintain existing steam systems. The primary bases of competition for this segment are price, technical capabilities, quality, timeliness of performance, breadth of products and services and willingness to accept project risks.

Nuclear Operations. We have specialized technical capabilities that have allowed us to be a valued supplier of nuclear components and fuel for the U.S. Government’s naval nuclear fleet since the 1950s. Because of the technical standards required to meet U.S. Government contracting requirements for nuclear components and the barriers to entry present in this type of environment, competition in this segment is limited. The primary bases of limited competition for this segment are price, high capital investment, technical capabilities and quality of products and services.

Technical Services. Through this segment, we are engaged in a highly competitive business through our management and operation of U.S. Government facilities. Many of our government contracts are bid as a joint venture with one or more companies, in which we may have a majority or a minority position. The performance of the prime or lead contractor can impact our reputation and our future competitive position with respect to that particular project and customer. Our primary competitors in the delivery of goods and services to the U.S. Government and the operation of U.S. Government facilities include Bechtel National, Inc., URS Corporation, CH2M Hill, Inc., Fluor Corporation, Lockheed Martin Corporation, Jacobs Engineering Group, Inc., EnergySolutions, Inc. and Northrop Grumman Corporation. The primary bases of competition for this segment are price, performance, availability of key personnel and technical capabilities.

Nuclear Energy. Our Nuclear Energy segment supplies commercial nuclear steam generators and components. In addition, this segment is actively designing the modular and scalable B&W mPower^TM reactor. B&W has supplied the nuclear industry with more than 1,300 large, heavy components worldwide. With manufacturing operations in the U.S. and Canada, this segment is the only heavy nuclear component manufacturer in North America. Our Nuclear Energy segment fabricates pressure vessels, reactors, steam generators, heat exchangers and other auxiliary equipment. This segment also provides specialized engineering and maintenance services, including services for plant outages and power plant construction. Through this segment, we compete with a number of companies specializing in nuclear capabilities including AREVA Inc., The Shaw Group Inc. and Westinghouse Electric Corporation. The primary bases of competition for this segment are price, technical capabilities, quality, timeliness of performance, breadth of products and services and willingness to accept project risks.

Joint Ventures

We participate in the ownership of a variety of entities with third parties, primarily through corporations, limited liability companies and partnerships, which we refer to as “joint ventures.” Our Power Generation segment enters into joint ventures primarily to enhance its manufacturing, design and global production operations. Through several joint venture arrangements, our Technical Services segment manages and operates nuclear facilities and associated plant infrastructure, manufactures components and assembles/dismantles nuclear devices, constructs large capital facilities, provides safeguards and security for inventory and assets, supports and conducts research and development for advanced energy technology and manages environmental programs for the DOE and the NNSA.

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We generally account for our investments in joint ventures under the equity method of accounting. Certain of our unconsolidated joint ventures are described below.

Power Generation

• Ebensburg Power Company & Ebensburg Investors Limited Partnership. Through these entities, which were formed by subsidiaries within our Power Generation segment and ESI Energy, Inc. in 1992, we own an interest in and operate a combined solid waste and cogeneration facility located in Cambria County near Ebensburg, Pennsylvania. This facility uses bituminous waste coal for its primary fuel and sells generated electricity to a utility.

• Halley & Mellowes Pty. Ltd. Diamond Power International, Inc. (“DPII”), one of our wholly owned subsidiaries, owns an interest in this Australian company, which was formed in 1984. Halley & Mellowes Pty. Ltd. sells soot blowers, boiler cleaning equipment, valves and material handling equipment, primarily in Australian markets, all of which are complementary to DPII’s product lines.

• Babcock & Wilcox Beijing Company, Ltd. We own equal interests in this entity with Beijing Jingcheng Machinery Electric Holding Company, Ltd. Babcock & Wilcox Beijing Company, Ltd. was formed in 1986 and is located in Beijing, China. Its main activities are the design, manufacture, production and sale of various power plant and industrial boilers. It operates the largest heavy drum shop in northern China. This entity expands our markets internationally and provides additional capacity to our Power Generation segment’s boiler business.

• Thermax Babcock & Wilcox Energy Solutions Private Limited. In June 2010, one of our subsidiaries and Thermax Ltd., a boiler manufacturer based in India, formed a joint venture to build subcritical and highly efficient supercritical boilers and pulverizers for the Indian utility boiler market. We have licensed to the joint venture our technology for subcritical boilers 300 MW and larger, highly efficient supercritical boilers and coal pulverizers. The joint venture is constructing a new 3,000 MW pressure parts facility in India, which we expect to be ready for operations by
mid-2013.

Technical Services

• Pantex Plant. Through Babcock & Wilcox Technical Services Pantex, LLC, a limited liability company we formed with Honeywell International Inc. and Bechtel National, Inc., we manage and operate the Pantex Plant for the DOE. The Pantex Plant is located on a 16,000-acre NNSA site near Amarillo, Texas. Key operations at this facility include evaluating, retrofitting and repairing nuclear devices; dismantling and sanitizing nuclear devices; developing, testing and fabricating high-explosive components; and handling and storing plutonium pits. (See Y-12 National Security Complex discussion below for further information).

• Y-12 National Security Complex. Through Babcock & Wilcox Technical Services Y-12, LLC, a limited liability company we formed with Bechtel National, Inc. and in which we own a majority interest, we manage and operate the Y-12 National Security Complex for the DOE. Y-12 is located on an 811-acre NNSA site in Oak Ridge, Tennessee. Operations at the site focus on the production, refurbishment and dismantlement of nuclear devices, storage of nuclear material and the prevention of the proliferation of weapons of mass destruction. On January 8, 2013, we were notified that our joint venture, Nuclear Production Partners, LLC (“NP2”), was not selected to lead the NNSA’s combined Management and Operating (“M&O”) contract for the Y-12 National Security Complex and Pantex Plant. On January 18, 2013, NP2 filed a protest against NNSA’s award of the M&O contract.

• Strategic Petroleum Reserve. Since 1993, this facility has been managed and operated by DM Petroleum Operations Company, an entity we co-owned with DynCorp International, International-Matex Tank and Terminals and Jacobs Engineering Group, Inc. The Strategic Petroleum Reserve stores an emergency supply of crude oil at four sites in huge underground salt caverns along the Texas and Louisiana Gulf Coast. We sold our interest in this entity during 2012.

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• Los Alamos National Laboratory. Since 2006, Los Alamos National Security, LLC, a limited liability company formed in 2005 with the University of California, Bechtel National, Inc., URS Corporation and BWX Technologies, Inc. (“BWXT”), has managed and operated the Los Alamos National Laboratory, a premier national security research institution, delivering scientific and engineering solutions for the nation’s most crucial and complex problems. Located in New Mexico, the Los Alamos National Laboratory conducts ongoing research and development on the measures necessary for certifying the safety and reliability of nuclear devices without the use of nuclear testing for the U.S. Government.

• Lawrence Livermore National Laboratory. Lawrence Livermore National Security, LLC, a limited liability company formed in 2006 with the University of California, Bechtel National, Inc., URS Corporation and BWXT, manages and operates Lawrence Livermore National Laboratory located in Livermore, California. The laboratory serves as a national resource in science and engineering, focused on national security, energy, the environment and bioscience, with special responsibility for nuclear devices.

• Savannah River Liquid Waste Disposition Program. In July 2009, Savannah River Remediation LLC, a limited liability company formed by URS Corporation, Bechtel National, Inc., CH2M Hill Constructors, Inc. and Babcock & Wilcox Technical Services Group, Inc. (“B&W TSG”) became the liquid waste contractor for the DOE’s Savannah River Site located in Aiken, South Carolina. The objective of this program is to achieve closure of the Savannah River Site liquid waste tanks in compliance with the Federal Facilities Agreement, utilizing the Defense Waste Processing Facility and Saltstone Facility.

• Nevada National Security Site. National Security Technologies, LLC (“NSTec”), a limited liability company formed by Northrop Grumman Corporation, AECOM Technology Corporation, CH2M Hill and B&W TSG manages and operates the Nevada Test Site and its related facilities and laboratories for the DOE. Located in Las Vegas, Nevada, NSTec works on projects for other federal agencies such as the Defense Threat Reduction Agency, NASA, the NRC and the U.S. Air Force, Army, and Navy. Missions include defense experimentation and stockpile stewardship, homeland security and defense applications and environmental management.

• Decontamination & Decommissioning Services. Babcock & Wilcox Shaw Remediation, LLC is a limited liability company formed by B&W TSG and Shaw Environmental & Infrastructure Inc. to provide environmental remediation services for the Bechtel Marine Propulsion Corporation at the Knolls Atomic Power Laboratory in New York, the Bettis Atomic Power Laboratory in Pennsylvania and the Naval Reactor Facility in Idaho.

• Portsmouth Gaseous Diffusion Plant D&D. Fluor-B&W Portsmouth, LLC is a limited liability company formed by Fluor Federal Services, Inc. and B&W TSG, to provide nuclear operations, decontamination and decommissioning services at the Portsmouth plant in Ohio.

• Uranium Conversion Operations. Babcock & Wilcox Conversion Services, LLC is a limited liability company formed by B&W TSG and URS Corporation to perform uranium conversion operations at the Paducah Gaseous Diffusion Plant in Kentucky and the Portsmouth Gaseous Diffusion Plant in Ohio.

• Advanced Mixed Waste Treatment Project (“AMWTP”). Idaho Treatment Group, LLC (“ITG”) is a limited liability company we formed with URS Energy & Construction and EnergySolutions Federal Services, Inc. ITG is responsible for management and operations at the DOE’s AMWTP located in Idaho Falls, Idaho. AMWTP’s purpose is to safely process and dispose of transuranic waste and mixed low-level waste at the Department’s Idaho Site Transuranic Storage Area while maintaining a fully operational facility.

• West Valley Demonstration Project Phase I Decommissioning and Facility Disposition. CH2M Hill-B&W West Valley is a limited liability company formed by CH2MHILL Constructors, Inc., B&W TSG and Environmental Chemical Corporation. Services provided include project management and support services, site operations, maintenance, utilities, high-level waste canister relocation, facility disposition, waste tank farm management, NRC-licensed disposal area management, waste management and nuclear materials disposition and safeguards and security.

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• Waste Isolation Pilot Plant. Nuclear Waste Partnership, LLC is a limited liability company formed by B&W TSG, URS Corporation and Areva Federal Services, LLC as the major subcontractor. The purpose of the partnership is to manage and operate DOE’s Waste Isolation Pilot Plant in Carlsbad, New Mexico.

Nuclear Energy

• BWB Maintenance Services. Through our subsidiary B&W Nuclear Maintenance Services, Inc., we formed a limited liability company, BWB Maintenance Services Company, LLC, in partnership with Bartlett Holdings Inc., to perform maintenance and project services for certain Progress Energy (subsequently acquired by Duke Energy) nuclear sites located in North Carolina, South Carolina and Florida.

Foreign Operations

We have foreign operations in our Power Generation and Nuclear Energy segments. Our Canadian operations serve the North American electric utility, industrial power and global nuclear utility markets. Our operations in Denmark provide comprehensive services to companies in the waste-to-energy sector of the power generation market, primarily in eastern and western Europe. Our joint venture in China primarily serves the power generation needs of the Chinese domestic and other utility markets. The functional currency of these entities is not the U.S. Dollar, and as a result, we are subject to exchange rate fluctuations that impact our financial position, results of operations and cash flows. Our combined Power Generation and Nuclear Energy segment revenues, net of intersegment revenues, and income derived from operations located outside of the United States, as well as the approximate percentages of our total consolidated and combined revenues and total consolidated and combined operating income, respectively, for each of the last three years were as follows (dollars in thousands):

	Revenues					Operating Income
	Amount		Percent of Consolidated			Amount		Percent of Consolidated
Year ended December 31, 2012	$	684,886		21	%	$	98,699		28	%
Year ended December 31, 2011	$	641,612		22	%	$	57,032		60	%
Year ended December 31, 2010	$	539,548		20	%	$	62,587		26	%

Our revenues exclude revenues attributable to our joint ventures accounted for under the equity method of accounting, while our operating income includes results from joint ventures accounted for under the equity method.

For additional information on the geographic distribution of our revenues, see Note 17 to our consolidated and combined financial statements included in this report.

Customers

We provide our products and services to a diverse customer base, including utilities and other power producers, businesses in various process industries, such as pulp and paper mills, petrochemical plants, oil refineries and steel mills and the U.S. Government. Our largest customers, as a percentage of our total consolidated and combined revenues, during the years ended December 31, 2012 and 2011 were as follows:

Year Ended December 31, 2012:
U.S. Government	34	%
Solid Waste Authority of Palm Beach County	3	%
Year Ended December 31, 2011:
U.S. Government	38	%
American Electric Power Company, Inc.	6	%

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The U.S. Government is the primary customer of our Nuclear Operations and Technical Services segments. Revenues from the U.S. Government comprised 99% and 98% of segment revenues for the years ended December 31, 2012 and 2011, respectively, in our Nuclear Operations segment. Revenues from the U.S. Government comprised 41% and 74% of segment revenues for the years ended December 31, 2012 and 2011, respectively, in our Technical Services segment.

Our non-U.S. Government customers that account for a significant portion of revenues in one year may represent an immaterial portion of revenues in subsequent years.

Raw Materials and Suppliers

Our operations use raw materials, such as carbon and alloy steels in various forms and components and accessories for assembly, which are available from numerous sources. We generally purchase these raw materials and components as needed for individual contracts. Our Power Generation and Nuclear Energy segments do not depend on a single source of supply for any significant raw materials. Our Nuclear Operations segment relies on several single-source suppliers for materials used in its products. We believe these suppliers are viable, and we and the U.S. Government expend significant effort to monitor and maintain the supplier base for our Nuclear Operations segment.

Although shortages of some raw materials have existed from time to time, no serious shortage exists at the present time.

Employees

At December 31, 2012, we employed approximately 14,000 persons worldwide. Approximately 3,500 of our employees were members of labor unions at December 31, 2012. Many of our operations are subject to union contracts, which we customarily renew periodically. We consider our relationships with our employees to be satisfactory.

Patents and Licenses

We currently hold a large number of U.S. and foreign patents and have patent applications pending. We have acquired patents and technology licenses and granted technology licenses to others when we have considered it advantageous for us to do so. Although in the aggregate our patents and licenses are important to us, we do not regard any single patent or license or group of related patents or licenses as critical or essential to our business as a whole. In general, we depend on our technological capabilities and the application of know-how, rather than patents and licenses, in the conduct of our various businesses.

Research and Development Activities

Our principal research and development activities are conducted primarily in Barberton, Ohio and Lynchburg, Virginia, and at our various manufacturing plants and engineering and design offices. Our Barberton facility is a world-class institution for the advancement and development of energy conversion and combustion systems, environmental emissions control processes, materials selection and manufacturing technologies for the power generation industry. Our research and development activities are related to the development and improvement of new and existing products and equipment, as well as conceptual and engineering evaluation for translation into practical applications. We charge to research and development cost the costs of research and development unrelated to specific contracts as incurred. Substantially all of these costs are in our Power Generation and Nuclear Energy segments and include costs related to the development of our modular nuclear reactor business, B&W mPower^TM. Research and development activities (including in-kind research and development services described below) totaled $173.9 million, $163.0 million and $102.1 million in the years ended December 31, 2012, 2011 and 2010, respectively, which include amounts paid for by our customers of $53.4 million, $56.6 million and $32.9 million, respectively. We expect to continue significant spending on research and development projects, as we continue development of the B&W mPower^TM reactor technology and other commercial nuclear development projects. Contractual arrangements for customer-sponsored research and development can vary on a case-by-case basis and include contracts, cooperative agreements and grants. In November 2012, our Nuclear Energy segment was selected as the winner of the DOE’s competitively bid Small Modular Reactor (“SMR”) Licensing Technical Support Program, and will receive funding that will support accelerated development of its B&W mPower™ SMR technology.

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During the years ended December 31, 2012 and 2011, we recognized $17.9 million and $16.6 million, respectively, of non-cash in-kind research and development costs (included above) related to services contributed by our minority partner to Generation mPower LLC (“GmP”), our majority-owned subsidiary formed in 2011 to oversee the program to develop the small modular nuclear power plant based on B&W mPower^TM technology.

Hazard Risks and Insurance

Our operations present risks of injury to or death of people, loss of or damage to property and damage to the environment. We have created loss control systems to assist us in the identification and treatment of the hazard risks presented by our operations, and we endeavor to make sure these systems are effective.

As loss control measures will not always be successful, we seek to establish various means of funding losses and liability related to incidents or occurrences. We primarily seek to do this through contractual protections, including waivers of consequential damages, indemnities, caps on liability, liquidated damage provisions, and access to the insurance of other parties. We also procure insurance, operate our own captive insurance company and/or establish funded or unfunded reserves. However, none of these methods will eliminate all risks.

Depending on competitive conditions, the nature of the work, industry custom and other factors, we may not be successful in obtaining adequate contractual protection from our customers and other parties against losses and liabilities arising out of or related to the performance of our work. The scope of the protection may be limited, may be subject to conditions and may not be supported by adequate insurance or other means of financing. In addition, we sometimes have difficulty enforcing our contractual rights with others following a material loss.

Similarly, insurance for certain potential losses or liabilities may not be available or may only be available at a cost or on terms we consider not to be economical. Insurers frequently react to market losses by ceasing to write or severely limiting coverage for certain exposures. Risks that we have frequently found difficult to cost-effectively insure against include, but are not limited to, business interruption, property losses from wind, flood and earthquake events, nuclear hazards, war and confiscation or seizure of property in some areas of the world, pollution liability, liabilities related to occupational health exposures (including asbestos), liability related to our executives participating in the management of certain outside entities, professional liability/errors and omissions coverage, the failure, misuse or unavailability of our information systems, the failure of security measures designed to protect our information systems from security breaches and liability related to risk of loss of our work in progress and customer-owned materials in our care, custody and control. In cases where we place insurance, we are subject to the credit worthiness of the relevant insurer(s), the available limits of the coverage, our retention under the relevant policy, exclusions in the policy and gaps in coverage.

Our operations in designing, engineering, manufacturing, constructing and servicing nuclear power equipment and components for our commercial nuclear utility customers, subject us to various risks, including, without limitation, damage to our customers’ property and third party claims for personal injury, environmental liability, death and property damage. To protect against liability for damage to a customer’s property, we endeavor to obtain waivers of liability and subrogation from the customer and its insurer and are usually named as an additional insured under the utility customer’s nuclear property policy. We also attempt to cap our overall liability in our contracts. To protect against liability from claims brought by third parties, we seek to be insured under the utility customer’s nuclear liability policies and have the benefit of the indemnity and limitation of any applicable liability provision of the Price-Anderson Act. The Price-Anderson Act limits the public liability of U.S. manufacturers and operators of licensed nuclear facilities and other parties who may be liable in respect of, and indemnifies them against, all claims in excess of a certain amount. This amount is determined by the sum of commercially available liability insurance plus certain retrospective premium assessments payable by operators of commercial nuclear reactors. For those sites where we provide environmental remediation services, we seek the same protection from our customers as we do for our other nuclear activities. The Price-Anderson Act, as amended, includes a sunset provision and requires renewal each time that it expires. Contracts that were entered into during a period of time that Price-Anderson was in full force and effect continue to receive the benefit of the Price-Anderson Act’s nuclear indemnity. The Price-Anderson Act is set to expire on December 31, 2025. We also provide nuclear fabrication and other services to the nuclear

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power industry in Canada. Canada’s Nuclear Liability Act generally conforms to international conventions and is conceptually similar to the Price-Anderson Act in the United States. Accordingly, indemnification protections and the possibility of exclusions under Canada’s Nuclear Liability Act are similar to those under the Price-Anderson Act in the United States.

Although we do not own or operate any nuclear reactors, we have some coverage under commercially available nuclear liability and property insurance for our facilities that are currently licensed to possess special nuclear materials. Substantially all of our Nuclear Operations segment contracts involving nuclear materials are covered by and subject to the nuclear indemnity provisions of either the Price-Anderson Act or Public Law 85-804 which, among other things, authorizes the DOE to indemnify certain contractors when such acts would facilitate national defense. However, to the extent the value of the nuclear materials in our care, custody or control exceeds the commercially available limits of our insurance, we potentially have underinsured risk of loss for such nuclear material.

Our Technical Services segment participates in the management and operation of various U.S. Government facilities. This participation is customarily accomplished through the participation in joint ventures with other contractors for any given facility. These activities involve, among other things, handling nuclear devices and their components from the aging stockpile of the U.S. Government. Insurable liabilities arising from these sites are rarely protected by our or our partners’ corporate insurance programs. Instead, we rely on government contractual agreements, insurance purchased specifically for a site and certain specialized self-insurance programs funded by the U.S. Government. The U.S. Government has historically fulfilled its contractual agreement to reimburse its contractors for covered claims, and we expect it to continue this process during our participation in the administration of these facilities. However, in most of these situations in which the U.S. Government is contractually obligated to pay, the payment obligation is subject to the availability of authorized government funds. The reimbursement obligation of the U.S. Government is also conditional, and provisions of the relevant contract or applicable law may preclude reimbursement.

Our wholly owned captive insurance subsidiary provides workers’ compensation, employer’s liability, commercial general liability and automotive liability insurance to support our operations. We may also have business reasons in the future to have our insurance subsidiary accept other risks that we cannot or do not wish to transfer to outside insurance companies. These risks may be considerable in any given year or cumulatively. Our insurance subsidiary has not provided significant amounts of insurance to unrelated parties. Claims, as a result of our operations, could adversely impact the ability of our insurance subsidiary to respond to all claims presented.

Additionally, upon the February 22, 2006 effectiveness of the settlement relating to the Chapter 11 proceedings involving several of our subsidiaries, most of our subsidiaries contributed substantial insurance rights to the asbestos personal injury trust, including rights to (1) certain pre-1979 primary and excess insurance coverages and (2) certain of our 1979-1986 excess insurance coverage. These insurance rights provided coverage for, among other things, asbestos and other personal injury claims, subject to the terms and conditions of the policies. The contribution of these insurance rights was made in exchange for the agreement on the part of the representatives of the asbestos claimants, including the representative of future claimants, to the entry of a permanent injunction, pursuant to Section 524(g) of the U.S. Bankruptcy Code, to channel to the asbestos trust all asbestos-related claims against our subsidiaries and former subsidiaries arising out of, resulting from or attributable to their operations, and the implementation of related releases and indemnification provisions protecting those subsidiaries and their affiliates from future liability for such claims. Although we are not aware of any significant, unresolved claims against our subsidiaries and former subsidiaries that are not subject to the channeling injunction and that relate to the periods during which such excess insurance coverage related, with the contribution of these insurance rights to the asbestos personal injury trust, it is possible that we could have underinsured or uninsured exposure for non-derivative asbestos claims or other personal injury or other claims that would have been insured under these coverages had the insurance rights not been contributed to the asbestos personal injury trust.

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Governmental Regulations and Environmental Matters

General

Many aspects of our operations and properties are affected by political developments and are subject to both domestic and foreign governmental regulations, including those relating to:

• constructing and equipping electric power and other industrial facilities;

• possessing and processing special nuclear materials;

• workplace health and safety;

• currency conversions and repatriation;

• taxation of foreign earnings and earnings of expatriate personnel; and

• protecting the environment.

We are required by various governmental and quasi-governmental agencies to obtain certain permits, licenses and certificates with respect to our operations. The kinds of permits, licenses and certificates required in our operations depend upon a number of factors.

We cannot determine the extent to which new legislation, new regulations or changes in existing laws or regulations may affect our future operations.

Environmental

Our operations and properties are subject to a wide variety of increasingly complex and stringent foreign, federal, state and local environmental laws and regulations, including those governing discharges into the air and water, the handling and disposal of solid and hazardous wastes, the remediation of soil and groundwater contaminated by hazardous substances and the health and safety of employees. Sanctions for noncompliance may include revocation of permits, corrective action orders, administrative or civil penalties and criminal prosecution. Some environmental laws provide for strict, joint and several liability for remediation of spills and other releases of hazardous substances, as well as damage to natural resources. In addition, companies may be subject to claims alleging personal injury or property damage as a result of alleged exposure to hazardous substances. Such laws and regulations may also expose us to liability for the conduct of or conditions caused by others or for our acts that were in compliance with all applicable laws at the time such acts were performed.

These laws and regulations include the Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended (“CERCLA”), the Clean Air Act, the Clean Water Act, the Resource Conservation and Recovery Act and similar laws that provide for responses to, and liability for, releases of hazardous substances into the environment. These laws and regulations also include similar foreign, state or local counterparts to these federal laws, which regulate air emissions, water discharges, hazardous substances and waste and require public disclosure related to the use of various hazardous substances. Our operations are also governed by laws and regulations relating to workplace safety and worker health, including the U.S. Occupational Safety and Health Act and regulations promulgated thereunder.

We are currently in the process of investigating and remediating some of our current and former operating sites. Although we have recorded reserves in connection with certain of these matters, due to the uncertainties associated with environmental remediation, we cannot assure you that the actual costs resulting from these remediation matters will not exceed the recorded reserves.

Our compliance with U.S. federal, state and local environmental control and protection regulations resulted in pretax charges of approximately $15.3 million, $13.2 million and $13.0 million in the years ended December 31, 2012, 2011 and 2010 respectively. In addition, compliance with existing environmental regulations necessitated capital expenditures of $3.2 million, $1.8 million and $0.5 million in the years ended December 31, 2012, 2011 and 2010, respectively. We expect to spend another $3.1 million on such capital expenditures over the next five years. We cannot predict all of the environmental requirements or circumstances that will exist in the future but anticipate that environmental control and protection standards will become increasingly stringent and costly. Based on our experience to date, we do not currently anticipate any material adverse effect on our business or consolidated financial condition as a result of future compliance with existing environmental laws and regulations. However,

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future events, such as changes in existing laws and regulations or their interpretation, more vigorous enforcement policies of regulatory agencies or stricter or different interpretations of existing laws and regulations, may require additional expenditures by us, which may be material. Accordingly, we can provide no assurance that we will not incur significant environmental compliance costs in the future.

We have been identified as a potentially responsible party at various cleanup sites under CERCLA. CERCLA and other environmental laws can impose liability for the entire cost of cleanup on any of the potentially responsible parties, regardless of fault or the lawfulness of the original conduct. Generally, however, where there are multiple responsible parties, a final allocation of costs is made based on the amount and type of wastes disposed of by each party and the number of financially viable parties, although this may not be the case with respect to any particular site. We have not been determined to be a major contributor of wastes to any of these sites. On the basis of our relative contribution of waste to each site, we expect our share of the ultimate liability for the various sites will not have a material adverse effect on our consolidated financial condition, results of operations or cash flows in any given year.

We perform significant amounts of work for the U.S. Government under both prime contracts and subcontracts and operate certain facilities that are licensed to possess and process special nuclear materials. As a result of these activities, we are subject to continuing reviews by governmental agencies, including the U.S. Environmental Protection Agency (the “EPA”) and the NRC.

The NRC’s decommissioning regulations require our Nuclear Operations segment to provide financial assurance that it will be able to pay the expected cost of decommissioning each of its licensed facilities at the end of its service life. We provided financial assurance aggregating $43.5 million during the year ended December 31, 2012 with existing letters of credit for the ultimate decommissioning of these licensed facilities. These two facilities have provisions in their government contracts pursuant to which substantially all of our decommissioning costs and financial assurance obligations are covered by the DOE, including the costs to complete the decommissioning projects underway at the Erwin, Tennessee facility. These letters of credit are to cover decommissioning required pursuant to work not subject to this DOE obligation.

The demand for power generation services and products can be influenced by state and federal governmental legislation setting requirements for utilities related to operations, emissions and environmental impacts. The legislative process is unpredictable and includes a platform that continuously seeks to increase the restrictions on power producers. Potential legislation limiting emissions from power plants, including carbon dioxide, could affect our markets and the demand for our products and services in our Power Generation segment.

At December 31, 2012 and 2011, we had total environmental reserves, including provisions for the facilities discussed above, of $49.6 million and $47.3 million, respectively. Of our total environmental reserves at December 31, 2012 and 2011, $3.1 million and $3.2 million, respectively, were included in current liabilities. Inherent in the estimates of those reserves and recoveries are our expectations regarding the levels of contamination, decommissioning costs and recoverability from other parties, which may vary significantly as decommissioning activities progress. Accordingly, changes in estimates could result in material adjustments to our operating results, and the ultimate loss may differ materially from the amounts we have provided for in our consolidated and combined financial statements.

Cautionary Statement Concerning Forward-Looking Statements

We are including the following discussion to inform our existing and potential security holders generally of some of the risks and uncertainties that can affect our company and to take advantage of the “safe harbor” protection for forward-looking statements that applicable federal securities law affords.

From time to time, our management or persons acting on our behalf make forward-looking statements to inform existing and potential security holders about our company. These statements may include projections and estimates concerning the timing and success of specific projects and our future backlog, revenues, income and capital spending. Forward-looking statements are generally accompanied by words such as “estimate,” “project,” “predict,” “believe,” “expect,” “anticipate,” “plan,” “seek,” “goal,” “could,” “intend”, “may,” “should” or other words that convey the uncertainty of future events or outcomes. In addition, sometimes we will specifically describe a statement as being a forward-looking statement and refer to this cautionary statement.

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In addition, various statements in this annual report on Form 10-K, including those that express a belief, expectation or intention, as well as those that are not statements of historical fact, are forward-looking statements. Those forward-looking statements appear in Item 1 – “Business” and Item 3 – “Legal Proceedings” in Part I of this report and in Item 7 – “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in the notes to our consolidated and combined financial statements in Item 8 of Part II of this report and elsewhere in this report.

These forward-looking statements include, but are not limited to, statements that relate to, or statements that are subject to risks, contingencies or uncertainties that relate to:

• our business strategy;

• future levels of revenues (including our backlog to the extent it may be viewed as an indicator of future revenues), operating margins, income from operations, net income or earnings per share;

• anticipated levels of demand for our products and services;

• future levels of research and development, capital, environmental or maintenance expenditures;

• our beliefs regarding the timing and effects on our businesses of certain environmental and tax legislation, rules or regulations;

• the success or timing of completion of ongoing or anticipated capital or maintenance projects;

• expectations regarding the acquisition or divestiture of assets and businesses;

• our ability to obtain and maintain appropriate insurance and indemnities;

• the potential effects of judicial or other proceedings, including tax audits, on our business or businesses, financial condition, results of operations and cash flows;

• the anticipated effects of actions of third parties such as competitors, or federal, foreign, state or local regulatory authorities, or plaintiffs in litigation;

• effective date and expected impact of accounting pronouncements; and

• our plans regarding the design, research and development, financing and deployment of the B&W mPower^TM reactor.

We have based our forward-looking statements on our current expectations, estimates and projections about our industries and our company. We caution that these statements are not guarantees of future performance and you should not rely unduly on them, as they involve risks, uncertainties and assumptions that we cannot predict. In addition, we have based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. While our management considers these assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. Accordingly, our actual results may differ materially from the future performance that we have expressed or forecast in our forward-looking statements. Differences between actual results and any future performance suggested in our forward-looking statements could result from a variety of factors, including the following:

• general economic and business conditions and industry trends;

• general developments in the industries in which we are involved;

• decisions on spending by the U.S. Government and power generating companies;

• the highly competitive nature of our businesses;

• cancellations of and adjustments to backlog and the resulting impact from using backlog as an indicator of future earnings;

• our ability to perform projects on time, in accordance with the schedules established by the applicable contracts with customers;

• the ability of our suppliers to deliver raw materials in sufficient quantities and in a timely manner;

• volatility and uncertainty of the credit markets;

• our ability to comply with covenants in our credit agreements and other debt instruments and availability, terms and deployment of capital;

• the impact of our unfunded pension liabilities on liquidity, and our ability to fund such liabilities in the future, including our ability to continue being reimbursed by the U.S. Government for a portion of our pension funding obligations, which is contingent on maintaining our government contracts;

• the continued availability of qualified personnel;

• the operating risks normally incident to our lines of business, including the potential impact of liquidated damages;

• changes in, or our failure or inability to comply with, government regulations;

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• adverse outcomes from legal and regulatory proceedings;

• impact of potential regional, national and/or global requirements to significantly limit or reduce greenhouse gas emissions in the future;

• our ability to successfully manage research and development projects, including our efforts to develop the small modular nuclear power plant based on B&W mPower^TM technology;

• impact of potential regulatory and industry response affecting the timing and cost of future nuclear development as a result of the March 11, 2011 earthquakes and tsunami on certain of Japan’s nuclear facilities;

• changes in, and liabilities relating to, existing or future environmental regulatory matters;

• rapid technological changes;

• the consequences of significant changes in interest rates and currency exchange rates;

• results of tax audits, including a determination by the IRS that the spin-off or certain transactions should be treated as a taxable transaction, and the realization of deferred tax assets;

• our ability to manage our capital structure, including our access to capital, credit ratings, debt and ability to raise additional financing;

• difficulties we may encounter in obtaining regulatory or other necessary approvals of any strategic transactions;

• the risks associated with integrating businesses we acquire;

• our ability to realize adequate returns and related dividends on our investments in unconsolidated affiliates;

• our ability to maintain operational support for our information systems against service outages and data corruption, as well as protection against cyber-based network security breaches and theft of data;

• social, political and economic situations in foreign countries where we do business;

• the possibilities of war, other armed conflicts or terrorist attacks;

• the effects of asserted and unasserted claims;

• our ability to obtain and maintain surety bonds, letters of credit, bank guarantees and financing;

• our ability to obtain and maintain builder’s risk, liability, property and other insurance in amounts and on terms we consider adequate and at rates that we consider economical;

• our ability to successfully develop competitive new technologies and products;

• the aggregated risks retained in our captive insurance subsidiary; and

• the impact of the loss of insurance rights as part of the Chapter 11 bankruptcy settlement concluded in 2006 involving several of our subsidiaries.

We believe the items we have outlined above are important factors that could cause estimates in our financial statements to differ materially from actual results and those expressed in a forward-looking statement made in this report or elsewhere by us or on our behalf. We have discussed many of these factors in more detail elsewhere in this report. These factors are not necessarily all the factors that could affect us. Unpredictable or unanticipated factors we have not discussed in this report could also have material adverse effects on actual results of matters that are the subject of our forward-looking statements. We do not intend to update our description of important factors each time a potential important factor arises, except as required by applicable securities laws and regulations. We advise our security holders that they should (1) be aware that factors not referred to above could affect the accuracy of our forward-looking statements and (2) use caution and common sense when considering our forward-looking statements.

Available Information

Our website address is www.babcock.com. We make available through the Investor Relations section of this website under “SEC Filings,” free of charge, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, statements of beneficial ownership of securities on Forms 3, 4 and 5 and amendments to those reports as soon as reasonably practicable after we electronically file those materials with, or furnish those materials to, the Securities and Exchange Commission (the “SEC”). You may read and copy any materials we file with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC 20549. You may obtain information regarding the Public Reference Room by calling the SEC at 1-800-SEC-0330. In addition, the SEC maintains a website at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC. We have also posted on our website our: Corporate Governance Principles; Code of Business Conduct; Code of Ethics for our Chief Executive Officer and Senior Financial Officers; Board of Directors Conflicts of Interest Policies and Procedures; Management, Board Members and Independent Director Contact Information; By-laws; and charters for the Audit & Finance, Governance, Compensation and Safety & Security Committees of our Board.

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Item 1A. RISK FACTORS

Risk Factors Related to Our Business

We derive substantial revenues from electric power generating companies and other steam-using industries, with demand for our products and services depending on capital expenditures in these historically cyclical industries. Additionally, recent legislative and regulatory developments relating to clean air legislation are impacting plans for new coal-fired power plants within the United States.

The demand for power generation products and services depends primarily on the capital expenditures of electric power generating companies, paper companies and other steam-using industries and expenditures by original equipment manufacturers. These capital expenditures are influenced by such factors as:

• prices for electricity, along with the cost of production and distribution;

• prices for natural resources such as coal and natural gas;

• demand for electricity, paper and other end products of steam-generating facilities;

• availability of other sources of electricity, paper or other end products;

• requirements of environmental legislation and regulation, including potential requirements applicable to carbon dioxide emissions;

• impact of potential regional, state, national and/or global requirements to significantly limit or reduce greenhouse gas emissions in the future;

• level of capacity utilization at operating power plants, paper mills and other steam-using facilities;

• requirements for maintenance and upkeep at operating power plants and paper mills to combat the accumulated effects of wear and tear;

• ability of electric generating companies and other steam users to raise capital; and

• relative prices of fuels used in boilers, compared to prices for fuels used in gas turbines and other alternative forms of generation.

A material decline in capital expenditures by electric power generating companies, paper companies and other steam-using industries over a sustained period of time could materially and adversely affect the demand for our power generation products and services and, therefore, our financial condition, results of operations and cash flows. U.S. coal-fired power plants have been scrutinized by environmental groups and government regulators over the emissions of potentially harmful pollutants. The recent economic environment and uncertainty concerning new environmental legislation or replacement rules or regulations has caused many of our major customers, principally electric utilities, to delay making substantial capital expenditures for new plants, as well as upgrades to existing power plants.

We rely on U.S. Government contracts for a large percentage of our revenue, and some of those contracts are subject to continued appropriations by Congress and may be terminated or delayed if future funding is not made available. In addition, the U.S. Government may not renew or may seek to modify our existing contracts.

For the year ended December 31, 2012, we relied on U.S. Government contracts for approximately 34% of our revenue. Government contracts are subject to various uncertainties, restrictions and regulations, including oversight audits, which could result in withholding or delaying of payments to us, and termination or modification at the U.S. Government’s convenience. In addition, some of our large, multi-year contracts with the U.S. Government are subject to annual funding determinations and the continuing availability of Congressional appropriations. Although multi-year operations may be planned in connection with major procurements, Congress generally appropriates funds on a fiscal-year basis even though a program may continue for several years. Consequently, programs often are only partially funded initially, and additional funds are committed only as Congress makes further appropriations. In years when the U.S. Government does not complete its budget process before the end of its fiscal year on September 30, government operations typically are funded through a continuing resolution that authorizes agencies of the U.S. Government to continue to operate, but does not authorize new spending initiatives. Congress

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has passed a continuing resolution to fund U.S. Government operations through March 27, 2013. When the U.S. Government operates under a continuing resolution, delays can occur in the procurement of products and services. As a result, we are subject to ongoing uncertainties associated with U.S. Government budget restraints and other factors affecting government funding.

In August 2011, Congress enacted the Budget Control Act of 2011, which committed the U.S. Government to significantly reducing the federal deficit over ten years. The Budget Control Act established caps on discretionary spending through 2021. It also called for substantial automatic spending cuts split between defense and non-defense programs scheduled to start in March 2013 and continue over a nine-year period. In January 2013, Congress enacted the American Taxpayer Relief Act of 2012, which addressed a number of tax code provisions and certain spending issues, but left in place the automatic spending cuts (although delaying their implementation to March 1, 2013). While we believe our programs are well aligned with national defense and other strategic priorities, the outcome of efforts underway to prevent the automatic spending cuts is uncertain and certain proposed defense spending reductions, if enacted, could adversely impact programs in which we provide products or services. In addition, these cuts could adversely affect the viability of the suppliers and subcontractors under our programs.

The U.S. Government typically can terminate or modify any of its contracts with us either for its convenience or if we default by failing to perform under the terms of the applicable contract. A termination arising out of our default could expose us to liability and have an adverse effect on our ability to compete for future contracts and orders. If any of our contracts reflected in backlog are terminated by the U.S. Government, our backlog would be reduced by the expected value of the remaining work under such contracts. In addition, on those contracts for which we are teamed with others and are not the prime contractor, the U.S. Government could terminate a prime contract under which we are a subcontractor, irrespective of the quality of our products and services as a subcontractor. The reduction or termination of funding, or changes in the timing of funding, for a U.S. Government program in which we provide products or services would result in a reduction or loss of anticipated future revenues attributable to that program and could have a negative impact on our results of operations.

We also have several significant contracts with the U.S. Government that are subject to periodic renewal and rebidding through a competitive process. If the U.S. Government fails to renew these contracts, our results of operations and cash flows would be adversely affected. In January 2013, we were notified that our joint venture was not selected for the combined M&O contract for the Y-12 National Security Complex and Pantex Plant, although the selection is under protest.

As a result of these and other factors, the termination of one or more of our significant government contracts, our suspension from government contract work, the failure of the U.S. Government to renew our existing contracts or the disallowance of the payment of our contract costs could have a material adverse effect on our financial condition, results of operations and cash flows.

Demand for our products and services is vulnerable to economic downturns and reductions in private sector and government spending.

Demand for our products and services has been, and we expect that demand will continue to be, subject to significant fluctuations due to a variety of factors beyond our control, including economic and industry conditions. We continued to experience uncertainty in 2012 from the global economic downturn in 2008-2009. Since 2008, concerns over inflation, energy costs, geopolitical issues, the availability and cost of credit and other market factors have contributed to increased volatility and diminished expectations for the global economy and expectations of slower global economic growth for the foreseeable future. Volatile oil and natural gas prices, low business and consumer confidence and high unemployment have remained despite economic improvements since 2009.

As a result, some of our customers have delayed, curtailed or cancelled proposed and existing projects and may continue to do so, which may decrease the overall demand for our products and services and adversely affect our results of operations.

In addition, our Nuclear Operations and Technical Services segments depend on U.S. Government funding, particularly funding levels at the DOE. Significant changes in the level of funding (for example, the annual budget of the DOE) or specifically mandated levels for individual programs that are important to our business could have an unfavorable impact on us. In addition, if Congress does not pass annual appropriations bills in a timely fashion,

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spending delays under our U.S. Government contracts may result. Any reduction in the level of U.S. Government funding, particularly at the DOE, may result in, among other things, a reduction in the number and scope of projects put out for bid by the U.S. Government or the curtailment of existing U.S. Government programs, either of which may result in a reduction in the number of contract award opportunities available to us, a reduction of activities at DOE sites and an increase in costs, including the costs of obtaining contract awards.

In addition, our customers may find it more difficult to raise capital in the future due to limitations on the availability of credit, increases in interest rates and other factors affecting the federal, municipal and corporate credit markets. Also, our customers may demand more favorable pricing terms and find it increasingly difficult to timely pay invoices for our services, which would impact our future cash flows and liquidity. Inflation or significant changes in interest rates could reduce the demand for our products and services. Any inability to timely collect our invoices may lead to an increase in our accounts receivables and potentially to increased write-offs of uncollectible invoices. If the economy weakens, or customer spending declines, then our backlog, revenues, net income and overall financial condition could deteriorate.

Our backlog is subject to unexpected adjustments and cancellations and may not be a reliable indicator of future revenues or earnings.

There can be no assurance that the revenues projected in our backlog will be realized or, if realized, will result in profits. Because of project cancellations or changes in project scope and schedule, we cannot predict with certainty when or if backlog will be performed. In addition, even where a project proceeds as scheduled, it is possible that contracted parties may default and fail to pay amounts owed to us or poor project performance could increase the cost associated with a project. Delays, suspensions, cancellations, payment defaults, scope changes and poor project execution could materially reduce or eliminate the revenues and profits that we actually realize from projects in backlog.

Reductions in our backlog due to cancellation or modification by a customer or for other reasons may adversely affect, potentially to a material extent, the revenues and earnings we actually receive from contracts included in our backlog. Many of the contracts in our backlog provide for cancellation fees in the event customers cancel projects. These cancellation fees usually provide for reimbursement of our out-of-pocket costs, revenues for work performed prior to cancellation and a varying percentage of the profits we would have realized had the contract been completed. However, we typically have no contractual right upon cancellation to the total revenues reflected in our backlog. Projects may remain in our backlog for extended periods of time. If we experience significant project terminations, suspensions or scope adjustments to contracts reflected in our backlog, our financial condition, results of operations and cash flows may be adversely impacted.

We are subject to risks associated with contractual pricing in our industries, including the risk that, if our actual costs exceed the costs we estimate on our fixed-price contracts, our profitability will decline, and we may suffer losses.

We are engaged in highly competitive industries, and we have priced a number of our projects on a fixed-price basis. Our actual costs could exceed our projections. We attempt to cover the increased costs of anticipated changes in labor, material and service costs of long-term contracts, either through estimates of cost increases, which are reflected in the original contract price, or through price escalation clauses. Despite these attempts, however, the cost and gross profit we realize on a fixed-price contract could vary materially from the estimated amounts because of supplier, contractor and subcontractor performance, changes in job conditions, variations in labor and equipment productivity and increases in the cost of labor and raw materials, particularly steel, over the term of the contract. These variations and the risks generally inherent in our industries may result in actual revenues or costs being different from those we originally estimated and may result in reduced profitability or losses on projects. Some of these risks include:

• difficulties encountered on our large-scale projects related to the procurement of materials or due to schedule disruptions, equipment performance failures, unforeseen site conditions or other factors that may result in additional costs to us, reductions in revenue, claims or disputes;

• our inability to obtain compensation for additional work we perform or expenses we incur as a result of our customers providing deficient design or engineering information or equipment or materials;

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• requirements to pay liquidated damages upon our failure to meet schedule or performance requirements of our contracts; and

• difficulties in engaging third party subcontractors, equipment manufacturers or materials suppliers or failures by third party subcontractors, equipment manufacturers or materials suppliers to perform could result in project delays and cause us to incur additional costs.

Changes in our effective tax rate and tax positions may vary.

We are subject to income taxes in the United States and numerous foreign jurisdictions. A change in tax laws, treaties or regulations, or their interpretation, in any country in which we operate could result in a higher tax rate on our earnings, which could have a material impact on our earnings and cash flows from operations. In addition, significant judgment is required in determining our worldwide provision for income taxes. In the ordinary course of our business, there are many transactions and calculations where the ultimate tax determination is uncertain. We are regularly under audit by tax authorities. Although we believe that our tax estimates and tax positions are reasonable, they could be materially affected by many factors including the final outcome of tax audits and related litigation, the introduction of new tax accounting standards, legislation, regulations and related interpretations, our global mix of earnings, the realizability of deferred tax assets and changes in uncertain tax positions. A significant increase in our tax rate could have a material adverse effect on our profitability and liquidity.

Our business could be negatively impacted by security threats, including physical and cybersecurity threats, and other disruptions.

We face various security threats, including cyber threats, threats to the physical security of our facilities and infrastructure (including those that we manage and operate for our customers), and threats from terrorist acts, as well as the potential for business disruptions associated with these threats. Although we utilize a combination of tailored and industry standard security measures and technology to monitor and mitigate these threats, we cannot guarantee that these measures and technology will be sufficient to prevent security threats from materializing.

We have been, and will likely continue to be, subject to cyber-based attacks and other attempts to threaten our information technology systems, including attempts to gain unauthorized access to our proprietary or classified information and attacks from computer hackers, viruses, malicious code and other security problems. As a U.S. Government contractor, we may be prone to a greater number of those threats than companies in other industries. From time to time, we experience system interruptions and delays; however, prior cyber-based attacks directed at us have not had a material adverse impact on our results of operations. Due to the evolving nature of these security threats, however, the impact of any future incident cannot be predicted.

The costs related to cyber or other security threats or disruptions may not be fully insured or indemnified by other means. Occurrence of any of these events could adversely affect our internal operations, the services we provide to customers, the value of our investment in research and development efforts and other intellectual property, our future financial results, our reputation or our stock price.

In addition, from time to time we may replace and/or upgrade current financial, human resources and other information technology systems. These activities subject us to inherent costs and risks associated with replacing and updating these systems, including potential disruption of our internal control structure, substantial capital expenditures, demands on management time and other risks of delays or difficulties in transitioning to new systems or of integrating new systems into our current systems. Our systems implementations and upgrades may not result in productivity improvements at the levels anticipated, or at all. In addition, the implementation of new technology systems may cause disruptions in our business operations. Such disruption and any other information technology system disruptions, and our ability to mitigate those disruptions, if not anticipated and appropriately mitigated, could have a material adverse effect on us.

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We rely on intellectual property law and confidentiality agreements to protect our intellectual property. We also rely on intellectual property we license from third parties. Our failure to protect our intellectual property rights, or our inability to obtain or renew licenses to use intellectual property of third parties, could adversely affect our business.

Our success depends, in part, on our ability to protect our proprietary information and other intellectual property. Our intellectual property could be stolen, challenged, invalidated, circumvented or rendered unenforceable. In addition, effective intellectual property protection may be limited or unavailable in some foreign countries where we operate.

Our failure to protect our intellectual property rights may result in the loss of valuable technologies or adversely affect our competitive business position. We rely significantly on proprietary technology, information, processes and know-how that are not subject to patent or copyright protection. We seek to protect this information through trade secret or confidentiality agreements with our employees, consultants, subcontractors or other parties, as well as through other security measures. These agreements and security measures may be inadequate to deter or prevent misappropriation of our confidential information. In the event of an infringement of our intellectual property rights, a breach of a confidentiality agreement or divulgence of proprietary information, we may not have adequate legal remedies to protect our intellectual property. Litigation to determine the scope of intellectual property rights, even if ultimately successful, could be costly and could divert management’s attention away from other aspects of our business. In addition, our trade secrets may otherwise become known or be independently developed by competitors.

In some instances, we have augmented our technology base by licensing the proprietary intellectual property of third parties. In the future, we may not be able to obtain necessary licenses on commercially reasonable terms.

Our use of percentage-of-completion method of accounting could result in volatility in our results of operations.

We generally recognize revenues and profits under our long-term contracts on a percentage-of-completion basis. Accordingly, we review contract price and cost estimates periodically as the work progresses and reflect adjustments proportionate to the percentage of completion in income in the period when we revise those estimates. To the extent these adjustments result in a reduction or an elimination of previously reported profits with respect to a project, we would recognize a charge against current earnings, which could be material. Our current estimates of our contract costs and the profitability of our long-term projects, although reasonably reliable when made, could change as a result of the uncertainties associated with these types of contracts, and if adjustments to overall contract costs are significant, the reductions or reversals of previously recorded revenue and profits could be material in future periods.

Maintaining adequate bonding and letter of credit capacity is necessary for us to successfully bid on and win various contracts.

In line with industry practice, we are often required to post standby letters of credit and surety bonds to support contractual obligations to customers as well as other obligations. These letters of credit and bonds generally indemnify customers should we fail to perform our obligations under the applicable contracts. If a letter of credit or bond is required for a particular project and we are unable to obtain it due to insufficient liquidity or other reasons, we will not be able to pursue that project. We utilize bonding facilities, but, as is typically the case, the issuance of bonds under each of those facilities is at the surety’s sole discretion. In addition, we have capacity limits under our credit facility for letters of credit. Moreover, due to events that affect the insurance and bonding and credit markets generally, bonding and letters of credit may be more difficult to obtain in the future or may only be available at significant additional cost. There can be no assurance that letters of credit or bonds will continue to be available to us on reasonable terms. Our inability to obtain adequate letters of credit and bonding and, as a result, to bid on new work could have a material adverse effect on our business, financial condition and results of operations. As of December 31, 2012, we had $217.3 million in letters of credit and bank guarantees, and $468.6 million in surety bonds outstanding.

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Volatility and uncertainty of the credit markets may negatively impact our ability to obtain financing.

We intend to finance our existing operations and initiatives with cash and cash equivalents, cash flows from operations, and potential borrowings, including under our revolving credit facility. Our ability to secure such borrowings will depend in part upon prevailing capital market conditions, as well as conditions in our business and our operating results; and those factors may affect our efforts to arrange financing on terms that are acceptable to us. The economic crisis in 2008 and 2009 and related financial industry turmoil resulted in a global tightening of credit markets and restricted access to capital. While we believe the credit markets have improved, uncertainty or deterioration in national or international economic conditions may adversely impact our ability to draw upon our revolving credit facility or obtain financing on favorable terms.

Our debt obligations and credit facility could restrict our operations.

The terms of our credit agreement impose various restrictions and covenants on us that could have adverse consequences, including:

• limiting our ability to react to changing economic, regulatory and industry conditions;

• limiting our ability to compete and our flexibility in planning for, or reacting to, changes in our business and the industry;

• limiting our ability to invest in joint ventures or acquire other companies;

• limiting our ability to pay dividends to our stockholders; and

• limiting our ability to borrow additional funds.

Our business strategy includes acquisitions to support our growth. Acquisitions of other businesses can create certain risks and uncertainties.

We intend to pursue growth through the acquisition of businesses or assets that we believe will enable us to strengthen our existing businesses and expand into new industries and regions. We may be unable to continue this growth strategy if we cannot identify suitable businesses or assets, reach agreement on potential strategic acquisitions on acceptable terms or for other reasons. Moreover, business acquisitions involve certain risks, including:

• difficulties relating to the assimilation of personnel, services and systems of an acquired business and the assimilation of marketing and other operational capabilities;

• challenges resulting from unanticipated changes in customer relationships subsequent to acquisition;

• additional financial and accounting challenges and complexities in areas such as tax planning, treasury management, financial reporting and internal controls;

• assumption of liabilities of an acquired business, including liabilities that were unknown at the time the acquisition transaction was negotiated;

• diversion of management’s attention from day-to-day operations;

• failure to realize anticipated benefits, such as cost savings and revenue enhancements;

• potentially substantial transaction costs associated with business combinations; and

• potential impairment of goodwill or other intangible assets resulting from the overpayment for an acquisition.

Acquisitions may be funded by the issuance of additional equity or debt financing, which may not be available on attractive terms. Moreover, to the extent an acquisition transaction financed by non-equity consideration results in goodwill, it will reduce our tangible net worth, which might have an adverse effect on potential credit and bonding capacity.

Additionally, an acquisition may bring us into businesses we have not previously conducted and expose us to additional business risks that are different than those we have historically experienced.

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Our business strategy also includes development and commercialization of new technologies to support our growth, which requires significant investment and involves various risks and uncertainties.

Our future growth will depend on our ability to continue to innovate by developing and commercializing new product and service offerings. Investments in new technologies involve varying degrees of uncertainties and risk. Commercial success depends on many factors, including the levels of innovation, the development costs and the availability of capital resources to fund those costs, the levels of competition from others developing similar or other competing technologies, our ability to obtain or maintain government permits or certifications, the effectiveness of production, distribution and marketing efforts, and the costs to customers to deploy and provide support for the new technologies. We may not achieve significant revenue from new product and service investments for a number of years, if at all. Moreover, new products and services may not be profitable, and, even if they are profitable, our operating margins from new products and services may not be as high as the margins we have experienced historically. In addition, new technologies may not be patentable and, as a result, we may face increased competition.

Among our opportunities involving new technologies, we are developing the B&W mPower™ reactor, a small modular reactor designed with the flexibility to provide between 180 MW to greater than 1,000 MW of electrical power generation (in increments of 180 MW), and the capability to operate for a four year cycle without refueling. The development, general and administrative and capital costs to develop and commercialize this technology will require a substantial amount of investment over a period of years, and the funding requirements may vary significantly from period to period. We intend to continue with our plan to seek third party funding, however, we can provide no assurance that such third party funding will be provided or that, if provided, it will be sufficient. Commercialization of this technology will require certification from the NRC. There can be no assurance that we will be successful in addressing all the technological challenges to developing and commercializing this technology or in obtaining the required NRC certification. Furthermore, while there currently are various small reactor competitors with limited capability, the potential exists for other competitors to emerge with competing technologies, in some cases with funding readily available, and we can provide no assurance that those competitors will not develop and commercialize similar or superior technologies sooner than we can or at a significant cost or price advantage.

Our operations are subject to operating risks, which could expose us to potentially significant professional liability, product liability, warranty and other claims. Our insurance coverage may be inadequate to cover all of our significant risks or our insurers may deny coverage of material losses we incur, which could adversely affect our profitability and overall financial condition.

We engineer, construct and perform services in large industrial facilities where accidents or system failures can have significant consequences. Risks inherent in our operations include:

• accidents resulting in injury or the loss of life or property;

• environmental or toxic tort claims, including delayed manifestation claims for personal injury or loss of life;

• pollution or other environmental mishaps;

• adverse weather conditions;

• mechanical failures;

• property losses;

• business interruption due to political action in foreign countries or other reasons; and

• labor stoppages.

Any accident or failure at a site where we have provided products or services could result in significant professional liability, product liability, warranty and other claims against us, regardless of whether our products or services caused the incident. We have been, and in the future we may be, named as defendants in lawsuits asserting large claims as a result of litigation arising from events such as those listed above.

We endeavor to identify and obtain in established markets insurance agreements to cover significant risks and liabilities. Insurance against some of the risks inherent in our operations is either unavailable or available only at rates or on terms that we consider uneconomical. Also, catastrophic events customarily result in decreased coverage limits, more limited coverage, additional exclusions in coverage, increased premium costs and increased deductibles

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and self-insured retentions. Risks that we have frequently found difficult to cost-effectively insure against include, but are not limited to, business interruption, property losses from wind, flood and earthquake events, nuclear hazards, war and confiscation or seizure of property in some areas of the world, pollution liability, liabilities related to occupational health exposures (including asbestos), professional liability/errors and omissions coverage, the failure, misuse or unavailability of our information systems, the failure of security measures designed to protect our information systems from security breaches, and liability related to risk of loss of our work in progress and customer-owned materials in our care, custody and control. Depending on competitive conditions and other factors, we endeavor to obtain contractual protection against certain uninsured risks from our customers. When obtained, such contractual indemnification protection may not be as broad as we desire or may not be supported by adequate insurance maintained by the customer. Such insurance or contractual indemnity protection may not be sufficient or effective under all circumstances or against all hazards to which we may be subject. A successful claim for which we are not insured or for which we are underinsured could have a material adverse effect on us. Additionally, disputes with insurance carriers over coverage may affect the timing of cash flows and, if litigation with the carrier becomes necessary, an outcome unfavorable to us may have a material adverse effect on our results of operations.

We are also involved in management and operating activities for the U.S. Government where we are the prime contractor, including the Y-12 National Security Complex and Pantex Plant facilities. These activities involved, among other things, handling nuclear devices and their components from the aging stockpile of the U.S. Government. Most insurable liabilities arising from these sites are not protected in our corporate insurance program. Instead, we rely on government contractual agreements, some insurance purchased specifically for the sites and certain specialized self-insurance programs funded by the U.S. Government. The U.S. Government has historically fulfilled its contractual agreement to reimburse for insurable claims, and we expect it to continue this process during our administration of these two facilities. However, it should be noted that, in most situations, the U.S. Government is contractually obligated to pay subject to the availability of authorized government funds. The reimbursement obligation of the U.S. Government is also conditional, and provisions of the relevant contract or applicable law may preclude reimbursement.

We have a captive insurance company subsidiary that provides us with various insurance coverages. Claims, as a result of our operations, could adversely impact the ability of our captive insurance company subsidiary to respond to all claims presented.

Additionally, upon the February 22, 2006 effectiveness of the settlement relating to the Chapter 11 proceedings involving several of our subsidiaries, most of our subsidiaries contributed substantial insurance rights providing coverage for, among other things, asbestos and other personal injury claims, to an asbestos personal injury trust. With the contribution of these insurance rights to the asbestos personal injury trust, we may have underinsured or uninsured exposure for non-derivative asbestos claims or other personal injury or other claims that would have been insured under these coverages had the insurance rights not been contributed to the asbestos personal injury trust.

Our nuclear operations subject us to various environmental, regulatory, financial and other risks.

Our operations in designing, engineering, manufacturing, supplying, constructing and maintaining nuclear fuel and nuclear power equipment and components subject us to various risks, including:

• potential liabilities relating to harmful effects on the environment and human health resulting from nuclear operations and the storage, handling and disposal of radioactive materials;

• unplanned expenditures relating to maintenance, operation, security, upgrades and repairs required by the NRC and other government agencies;

• limitations on the amounts and types of insurance commercially available to cover losses that might arise in connection with nuclear operations; and

• potential liabilities arising out of a nuclear incident, whether or not it is within our control.

Our nuclear operations are subject to various safety-related requirements imposed by the U.S. Government, the DOE and the NRC. In the event of non-compliance, these agencies might increase regulatory oversight, impose fines or shut down our operations, depending upon the assessment of the severity of the situation. Revised security and safety requirements promulgated by these agencies could necessitate substantial capital and other expenditures.

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Limitations or modifications to indemnification regulations of the U.S. or foreign countries could adversely affect our business.

The Price-Anderson Act partially indemnifies the nuclear industry against liability arising from nuclear incidents in the United States, while ensuring compensation for the general public. The Price-Anderson Act comprehensively regulates the manufacture, use and storage of radioactive materials, while promoting the nuclear industry by offering broad indemnification to commercial nuclear power plant operators and DOE contractors. Because we provide nuclear fabrication and other services to the DOE relating to its nuclear devices, facilities and other programs and the nuclear power industry in the ongoing maintenance and modifications of its nuclear power plants, including the manufacture of equipment and other components for use in such nuclear power plants, we may be entitled to some of the indemnification protections under the Price-Anderson Act against liability arising from nuclear incidents in the United States. The indemnification authority under the Price-Anderson Act was extended through December 2025 by the Energy Policy Act of 2005. We also provide nuclear fabrication and other services to the nuclear power industry in Canada. Canada’s Nuclear Liability Act generally conforms to international conventions and is conceptually similar to the Price-Anderson Act in the United States. Accordingly, indemnification protections and the possibility of exclusions under Canada’s Nuclear Liability Act are similar to those under the Price-Anderson Act in the United States.

The Price-Anderson Act’s indemnification provisions may not apply to all liabilities that we might incur while performing services as a contractor for the DOE and the nuclear power industry. If an incident or evacuation is not covered under the Price-Anderson Act’s indemnification provisions, we could be held liable for damages, regardless of fault, which could have an adverse effect on our results of operations and financial condition. In connection with the international transportation of toxic, hazardous and radioactive materials, it is possible for a claim to be asserted which may not fall within the indemnification provided by the Price-Anderson Act. If such indemnification authority is not applicable in the future, our business could be adversely affected if the owners and operators of nuclear power plants fail to retain our services in the absence of commercially adequate insurance and indemnification.

Moreover, because we manufacture nuclear components for the U.S. Government’s defense program, we may be entitled to some of the indemnification protections afforded by Public Law 85-804 for certain of our nuclear operations risks. Public Law 85-804 authorizes certain agencies of the U.S. Government, such as the DOE and the U.S. Department of Defense, to indemnify their contractors against unusually hazardous or nuclear risks when such action would facilitate the national defense. However, because the indemnification protections afforded by Public Law 85-804 are granted on a discretionary basis, situations could arise where the U.S. Government elects not to offer such protections. In such situations, our business could be adversely affected by either our inability to obtain commercially adequate insurance or indemnification or our refusal to pursue such operations in the absence of such protections.

We are subject to government regulations that may adversely affect our future operations.

Many aspects of our operations and properties are affected by political developments and are subject to both domestic and foreign governmental regulations, including those relating to:

• constructing and manufacturing power generation products and nuclear components;

• currency conversions and repatriation;

• clean air and other environmental protection legislation;

• taxation of foreign earnings and earnings of expatriate personnel; and

• use of local employees and suppliers.

In addition, a substantial portion of the demand for our products and services is from electric power generating companies and other steam-using customers. The demand for power generation products and services can be influenced by state and federal governmental legislation setting requirements for utilities related to operations, emissions and environmental impacts. The legislative process is unpredictable and includes a platform that continuously seeks to increase the restrictions on power producers. Potential legislation limiting emissions from power plants, including carbon dioxide, could affect our markets and the demand for our products and services related to power generation.

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We cannot determine the extent to which our future operations and earnings may be affected by new legislation, new regulations or changes in existing regulations.

New regulations related to “conflict minerals” may force us to incur additional expenses, may make our supply chain more complex and may result in damage to our reputation with customers.

On August 22, 2012, under the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010 (“Dodd-Frank Act”), the SEC adopted new requirements for companies that use certain minerals and metals, known as conflict minerals, in their products, whether or not these products are manufactured by third parties. We are currently evaluating whether these requirements apply to us. These requirements will require companies that are subject to the rules to conduct due diligence, and disclose and report whether or not such minerals originate from the Democratic Republic of Congo and adjoining countries. The implementation of these new requirements could adversely affect the sourcing, availability and pricing of minerals used in the manufacture of certain components incorporated in our products. In addition, to the extent the rules apply to us, we will incur additional costs to comply with the disclosure requirements, including costs related to determining the source of any of the relevant minerals and metals used in our products. Since our supply chain is complex, we may not be able to sufficiently verify the origins for these minerals and metals used in our products through the diligence procedures that we implement, which may harm our reputation. In such event, we may also face difficulties in satisfying customers who require that all of the components of our products are certified as conflict mineral free.

Our businesses require us to obtain, and to comply with, national, state and local government permits and approvals.

Our businesses are required to obtain, and to comply with, national, state and local government permits and approvals. Any of these permits or approvals may be subject to denial, revocation or modification under various circumstances. Failure to obtain or comply with the conditions of permits or approvals may adversely affect our operations by temporarily suspending our activities or curtailing our work and may subject us to penalties and other sanctions. Although existing licenses are routinely renewed by various regulators, renewal could be denied or jeopardized by various factors, including:

• failure to provide adequate financial assurance for decommissioning or closure;

• failure to comply with environmental and safety laws and regulations or permit conditions;

• local community, political or other opposition;

• executive action; and

• legislative action.

In addition, if new environmental legislation or regulations are enacted or implemented, or existing laws or regulations are amended or are interpreted or enforced differently, we may be required to obtain additional operating permits or approvals. Our inability to obtain, and to comply with, the permits and approvals required for our businesses could have a material adverse effect on us.

Our operations involve the handling, transportation and disposal of radioactive and hazardous materials, and environmental laws and regulations and civil liability for contamination of the environment or related personal injuries may result in increases in our operating costs and capital expenditures and decreases in our earnings and cash flows.

Our operations involve the handling, transportation and disposal of radioactive and hazardous materials, including nuclear devices and their components. Failure to properly handle these materials could pose a health risk to humans or wildlife and could cause personal injury and property damage (including environmental contamination). If an accident were to occur, its severity could be significantly affected by the volume of the materials and the speed of corrective action taken by emergency response personnel, as well as other factors beyond our control, such as weather and wind conditions. Actions taken in response to an accident could result in significant costs.

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Governmental requirements relating to the protection of the environment, including solid waste management, air quality, water quality, the decontamination and decommissioning of nuclear manufacturing and processing facilities and cleanup of contaminated sites, have had a substantial impact on our operations. These requirements are complex and subject to frequent change. In some cases, they can impose liability for the entire cost of cleanup on any responsible party without regard to negligence or fault and impose liability on us for the conduct of others or conditions others have caused, or for our acts that complied with all applicable requirements when we performed them. Our compliance with amended, new or more stringent requirements, stricter interpretations of existing requirements or the future discovery of contamination may require us to make material expenditures or subject us to liabilities that we currently do not anticipate. Such expenditures and liabilities may adversely affect our business, financial condition, results of operations and cash flows. In addition, some of our operations and the operations of predecessor owners of some of our properties have exposed us to civil claims by third parties for liability resulting from alleged contamination of the environment or personal injuries caused by releases of hazardous substances into the environment. See “Business—Governmental Regulations and Environmental Matters.”

In our contracts, we seek to protect ourselves from liability associated with accidents, but there can be no assurance that such contractual limitations on liability will be effective in all cases or that our or our customers’ insurance will cover all the liabilities we have assumed under those contracts. The costs of defending against a claim arising out of a nuclear incident or precautionary evacuation, and any damages awarded as a result of such a claim, could adversely affect our results of operations and financial condition.

We maintain insurance coverage as part of our overall risk management strategy and due to requirements to maintain specific coverage in our financing agreements and in many of our contracts. These policies do not protect us against all liabilities associated with accidents or for unrelated claims. In addition, comparable insurance may not continue to be available to us in the future at acceptable prices, or at all.

We conduct a portion of our operations through joint venture entities, over which we may have limited ability to influence.

We currently have equity interests in several significant joint ventures and may enter into additional joint venture arrangements in the future. We do not manage all of these entities. Even in those joint ventures that we manage, we are often required to consider the interests of our joint venture partners in connection with major decisions concerning the operations of the joint ventures. In any case, differences in views among the joint venture participants may result in delayed decisions or disputes. We also cannot control the actions of our joint venture participants. We sometimes have joint and several liabilities with our joint venture partners under the applicable contracts for joint venture projects and we cannot be certain that our partners will be able to satisfy any potential liability that could arise. These factors could potentially harm the business and operations of a joint venture and, in turn, our business and operations.

Operating through joint ventures in which we are minority holders results in us having limited control over many decisions made with respect to projects and internal controls relating to projects. These joint ventures may not be subject to the same requirements regarding internal controls and internal control over financial reporting that we follow. As a result, internal control problems may arise with respect to the joint ventures that could adversely affect our ability to respond to requests or contractual obligations to customers or to meet the internal control requirements to which we are otherwise subject.

In addition, our arrangements involving joint ventures may restrict us from gaining access to the cash flows or assets of these entities. In some cases, our joint ventures have governmentally imposed restrictions on their abilities to transfer funds to us.

If our co-venturers fail to perform their contractual obligations on a project or if we fail to coordinate effectively with our co-venturers, we could be exposed to legal liability, loss of reputation and reduced profit on the project.

We often perform projects jointly with third parties. For example, we enter into contracting consortia and other contractual arrangements to bid for and perform jointly on large projects. Success on these joint projects depends in part on whether our co-venturers fulfill their contractual obligations satisfactorily. If any one or more of these third parties fail to perform their contractual obligations satisfactorily, we may be required to make additional investments and provide added services in order to compensate for that failure. If we are unable to adequately address any such performance issues, then our customer may exercise its right to terminate a joint project, exposing us to legal liability, loss of reputation and reduced profit.

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Our collaborative arrangements also involve risks that participating parties may disagree on business decisions and strategies. These disagreements could result in delays, additional costs and risks of litigation. Our inability to successfully maintain existing collaborative relationships or enter into new collaborative arrangements could have a material adverse effect on our results of operations.

Employee, agent or partner misconduct or our overall failure to comply with laws or regulations could weaken our ability to win contracts, lead to the suspension of our operations and result in reduced revenues and profits.

Misconduct, fraud, non-compliance with applicable laws and regulations, or other improper activities by one or more of our employees, agents or partners could have a significant negative impact on our business and reputation. Such misconduct could include the failure to comply with government procurement regulations, regulations regarding the protection of classified information, regulations regarding the pricing of labor and other costs in government contracts, regulations on lobbying or similar activities, regulations pertaining to the internal controls over financial reporting and various other applicable laws or regulations. For example, we regularly provide services that may be highly sensitive or that are related to critical national security matters; if a security breach were to occur, our ability to procure future government contracts could be severely limited. The precautions we take to prevent and detect these activities may not be effective, and we could face unknown risks or losses.

We are routinely audited and reviewed by the U.S. Government and its agencies. These agencies review our performance under our contracts, our cost structure and our compliance with applicable laws, regulations and standards, as well as the adequacy of, and our compliance with, our internal control systems and policies. Systems that are subject to review include our purchasing systems, billing systems, property management and control systems, cost estimating systems, compensation systems and management information systems. Any costs found to be improperly allocated to a specific contract will not be reimbursed or must be refunded if already reimbursed. If an audit or review uncovers improper or illegal activities, we could be subject to civil and criminal penalties and administrative sanctions, including termination of contracts, forfeiture of profits, suspension of payments, fines, loss of security clearance and suspension or debarment from contracting with the U.S. Government. In addition, we could suffer serious reputational harm if allegations of impropriety were made against us.

We could be adversely affected by violations of the U.S. Foreign Corrupt Practices Act.

The U.S. Foreign Corrupt Practices Act (“FCPA”) generally prohibits companies and their intermediaries from making improper payments to non-U.S. officials. Our training program and policies mandate compliance with the FCPA. We operate in some parts of the world that have experienced governmental corruption to some degree, and, in certain circumstances, strict compliance with anti-bribery laws may conflict with local customs and practices. If we are found to be liable for violations of the FCPA (either due to our own acts or our inadvertence, or due to the acts or inadvertence of others, including employees of our joint ventures), we could suffer from civil and criminal penalties or other sanctions.

We may not be able to compete successfully against current and future competitors.

Some of our competitors or potential competitors have greater financial or other resources than we have. Our operations may be adversely affected if our current competitors or new market entrants introduce new products or services with better features, performance, prices or other characteristics than those of our products and services. Furthermore, we operate in industries where capital investment is critical. We may not be able to obtain as much purchasing and borrowing leverage and access to capital for investment as an independent public company, which may impair our ability to compete against competitors or potential competitors.

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The loss of the services of one or more of our key personnel, or our failure to attract, assimilate and retain trained personnel in the future, could disrupt our operations and result in loss of revenues.

Our success depends on the continued active participation of our executive officers and key operating personnel. The unexpected loss of the services of any one of these persons could adversely affect our operations.

Our operations require the services of employees having the technical training and experience necessary to obtain the proper operational results. As such, our operations depend, to a considerable extent, on the continuing availability of such personnel. If we should suffer any material loss of personnel to competitors or be unable to employ additional or replacement personnel with the requisite level of training and experience to adequately operate our business, our operations could be adversely affected. While we believe our wage rates are competitive and our relationships with our employees are satisfactory, a significant increase in the wages paid by other employers could result in a reduction in our workforce, increases in wage rates, or both. If either of these events occurred for a significant period of time, our financial condition, results of operations and cash flows could be adversely impacted.

We may be unable to realize expected benefits from our Global Competitiveness Initiative and our profitability may be hurt or our business otherwise might be adversely affected.

In order to operate more efficiently and control costs, in 2012 we launched B&W’s Global Competitiveness Initiative, which includes operational and functional efficiency improvements, organizational design changes and manufacturing optimization. These plans are intended to generate operating expense savings through direct and indirect overhead expense reductions as well as other savings. These types of cost reduction and restructuring activities are complex. If we do not successfully manage our current restructuring activities, or any other restructuring activities that we may undertake in the future, expected efficiencies and benefits might be delayed or not realized, and our operations and business could be disrupted. Risks associated with these actions and other workforce management issues include delays, additional unexpected costs, changes in restructuring plans that increase or decrease the number of employees affected, adverse effects on employee morale and the failure to meet operational targets due to the loss of employees, any of which may impair our ability to achieve anticipated cost reductions or may otherwise harm our business, which could have a material adverse effect on our competitive position, results of operations, cash flows or financial condition.

Negotiations with labor unions and possible work stoppages and other labor problems could divert management attention and disrupt operations. In addition, new collective bargaining agreements or amendments to agreements could increase our labor costs and operating expenses.

A significant number of our employees are members of labor unions. If we are unable to negotiate acceptable new contracts with our unions in the future, we could experience strikes or other work stoppages by the affected employees. If any such strikes or other work stoppages were to occur, we could experience a significant disruption of operations. In addition, negotiations with unions could divert management attention. New union contracts could result in increased operating costs, as a result of higher wages or benefit expenses, for both union and nonunion employees. If nonunion employees were to unionize, we would experience higher ongoing labor costs.

Pension and medical expenses associated with our retirement benefit plans may fluctuate significantly depending on changes in actuarial assumptions, future market performance of plan assets, future trends in health care costs and legislative or other regulatory actions.

A substantial portion of our current and retired employee population is covered by pension and postretirement benefit plans, the costs and funding requirements of which depend on our various assumptions, including estimates of rates of return on benefit-related assets, discount rates for future payment obligations, rates of future cost growth and trends for future costs. Variances from these estimates could have a material adverse effect on us. In addition, funding requirements for benefit obligations of our pension and postretirement benefit plans are subject to legislative and other government regulatory actions. As of December 31, 2012, our defined benefit pension and postretirement benefit plans were underfunded by approximately $731.2 million. For additional information regarding our pension plans and postretirement benefits, see Note 6 to the consolidated and combined financial statements for the years ended December 31, 2012, 2011 and 2010 included in this report.

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Our internal controls over financial reporting may not be sufficient to achieve all stated goals and objectives.

Our internal controls and procedures were developed through a process in which our management applied its judgment in assessing the costs and benefits of such controls and procedures, which, by their nature, can provide only reasonable assurance regarding the control objectives. You should note that the design of any system of internal controls and procedures is based in part upon various assumptions about the likelihood of future events, and we cannot assure you that any design will succeed in achieving its stated goals under all potential future conditions, regardless of how remote.

Our Nuclear Operations segment relies on several single-source suppliers, which could, under certain circumstances, adversely affect our revenues and operating results.

Our Nuclear Operations segment relies on several single-source suppliers for materials used in its products. If the supply of a single-sourced material is delayed or ceases, we may not be able to produce the related product in a timely manner or in sufficient quantities, if at all, which could adversely affect our revenues and operating results. In addition, a single-source supplier of a key component could potentially exert significant bargaining power over price, quality, warranty claims, or other terms relating to the single-sourced materials.

Our international operations are subject to political, economic and other uncertainties not generally encountered in our domestic operations.

We derive a substantial portion of our revenues and equity in income of investees from international operations. Our international operations are subject to political, economic and other uncertainties not generally encountered in our U.S. operations. These include:

• risks of war, terrorism and civil unrest;

• expropriation, confiscation or nationalization of our assets;

• renegotiation or nullification of our existing contracts;

• changing political conditions and changing laws and policies affecting trade and investment;

• overlap of different tax structures; and

• risk of changes in foreign currency exchange rates.

Various foreign jurisdictions have laws limiting the right and ability of foreign subsidiaries and joint ventures to pay dividends and remit earnings to affiliated companies. Our international operations sometimes face the additional risks of fluctuating currency values, hard currency shortages and controls of foreign currency exchange.

Future natural disasters or other events beyond our control could adversely impact our business.

Natural disasters, such as earthquakes, tsunamis, hurricanes, floods, tornados, or other events could adversely impact demand for or supply of our products. In addition, natural disasters could also cause disruption to our facilities, systems or projects, which could interrupt operational processes and performance on our contracts and adversely impact our ability to manufacture our products and provide services and support to our customers. We operate facilities in areas of the world that are exposed to natural disasters, such as, but not limited to, hurricanes, floods and tornados.

War, other armed conflicts or terrorist attacks could have a material adverse effect on our business.

The wars in Iraq and Afghanistan and terrorist attacks and unrest have caused and may continue to cause instability in the world’s financial and commercial markets and have significantly increased political and economic instability in some of the geographic areas in which we operate. Threats of war or other armed conflict may cause further disruption to financial and commercial markets. In addition, continued unrest could lead to acts of terrorism

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in the United States or elsewhere, and acts of terrorism could be directed against companies such as ours. Also, acts of terrorism and threats of armed conflicts in or around various areas in which we operate could limit or disrupt our markets and operations, including disruptions from evacuation of personnel, cancellation of contracts or the loss of personnel or assets. Armed conflicts, terrorism and their effects on us or our markets may significantly affect our business and results of operations in the future.

We are subject to continuing contingent liabilities of MII as a result of the spin-off.

With completion of the spin-off, there are several significant areas where the liabilities of MII may become our obligations. For example, under the Internal Revenue Code of 1986, as amended (the “Code”) and the related rules and regulations, each corporation that was a member of our consolidated tax reporting group during any taxable period or portion of any taxable period ending on or before the effective time of the spin-off is jointly and severally liable for the federal income tax liability of our entire consolidated tax reporting group for that taxable period. We have entered into a tax sharing agreement with a subsidiary of MII that allocates the responsibility for prior period taxes of our consolidated tax reporting group between us and MII and its subsidiaries. However, if the subsidiary of MII were unable to pay, we could be required to pay the entire amount of such taxes. Other provisions of federal law establish similar liability for other matters, including laws governing tax-qualified pension plans as well as other contingent liabilities.

The spin-off could result in substantial tax liability.

MII has obtained a private letter ruling from the IRS substantially to the effect that, for U.S. federal income tax purposes, the spin-off qualified under Section 355 of the Code and certain transactions related to the spin-off qualified under Sections 355 and/or 368 of the Code. If the factual assumptions or representations made in the private letter ruling request are inaccurate or incomplete in any material respect, then we will not be able to rely on the ruling. Furthermore, the IRS will not rule on whether a distribution such as the spin-off satisfies certain requirements necessary to obtain tax-free treatment under Section 355 of the Code. Rather, the private letter ruling is based on representations by MII that those requirements have been satisfied, and any inaccuracy in those representations could invalidate the ruling.

Under the terms of the tax sharing agreement we entered into in connection with the spin-off, we are generally responsible for any taxes imposed on us or MII and its subsidiaries in the event that the spin-off and/or certain related preparatory transactions were to fail to qualify for tax-free treatment. However, if the spin-off and/or certain related preparatory transactions were to fail to qualify for tax-free treatment because of actions or failures to act by MII or its subsidiaries, a subsidiary of MII would be responsible for all such taxes. If we are liable for taxes under the tax sharing agreement, that liability could have a material adverse effect on us.

Potential indemnification liabilities to MII pursuant to the master separation agreement could materially adversely affect our company.

The master separation agreement with MII provides for, among other things, the principal corporate transactions required to effect the spin-off, certain conditions to the spin-off and provisions governing the relationship between our company and MII with respect to and resulting from the spin-off. Among other things, the master separation agreement provides for indemnification obligations designed to make our company financially responsible for substantially all liabilities that may exist relating to our business activities, whether incurred prior to or after the spin-off, as well as those obligations of MII assumed by us pursuant to the master separation agreement. If we are required to indemnify MII under the circumstances set forth in the master separation agreement, we may be subject to substantial liabilities.

In connection with our separation from MII, MII will indemnify us for certain liabilities. However, there can be no assurance that the indemnity will be sufficient to insure us against the full amount of such liabilities, or that MII’s ability to satisfy its indemnification obligation will not be impaired in the future.

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Pursuant to the master separation agreement, MII has agreed to indemnify us for certain liabilities. However, third parties could seek to hold us responsible for any of the liabilities that MII has agreed to retain, and there can be no assurance that the indemnity from MII will be sufficient to protect us against the full amount of such liabilities, or that MII will be able to fully satisfy its indemnification obligations. Moreover, even if we ultimately succeed in recovering from MII any amounts for which we are held liable, we may be temporarily required to bear these losses, which could have a material adverse effect on our liquidity.

Risks Relating to Ownership of Our Common Stock

Provisions in our corporate documents and Delaware law could delay or prevent a change in control of our company, even if that change may be considered beneficial by some stockholders.

The existence of some provisions of our certificate of incorporation and bylaws and Delaware law could discourage, delay or prevent a change in control of our company that a stockholder may consider favorable. These include provisions:

• providing that our board of directors fixes the number of members of the board;

• providing for the division of our board of directors into three classes with staggered terms;

• limiting who may call special meetings of stockholders;

• prohibiting stockholder action by written consent, thereby requiring stockholder action to be taken at a meeting of the stockholders;

• establishing advance notice requirements for nominations of candidates for election to our board of directors or for proposing matters that can be acted on by stockholders at stockholder meetings;

• establishing supermajority vote requirements for certain amendments to our certificate of incorporation and bylaws;

• limiting the right of stockholders to remove directors;

• authorizing a large number of shares of common stock that are not yet issued, which would allow our board of directors to issue shares to persons friendly to current management, thereby protecting the continuity of our management, or which could be used to dilute the stock ownership of persons seeking to obtain control of us; and

• authorizing the issuance of “blank check” preferred stock, which could be issued by our board of directors to increase the number of outstanding shares and thwart a takeover attempt.

In addition, we are subject to Section 203 of the Delaware General Corporation Law, which may have an anti-takeover effect with respect to transactions not approved in advance by our board of directors, including discouraging takeover attempts that might result in a premium over the market price for shares of our common stock.

We believe these provisions protect our stockholders from coercive or otherwise unfair takeover tactics by requiring potential acquirors to negotiate with our board of directors and by providing our board of directors with more time to assess any acquisition proposal, and are not intended to make our company immune from takeovers. However, these provisions apply even if the offer may be considered beneficial by some stockholders and could delay or prevent an acquisition that our board of directors determines is not in the best interests of our company and our stockholders.

We may issue preferred stock that could dilute the voting power or reduce the value of our common stock.

Our certificate of incorporation authorizes us to issue, without the approval of our stockholders, one or more classes or series of preferred stock having such designation, powers, preferences and relative, participating, optional and other special rights, including preferences over our common stock respecting dividends and distributions, as our board of directors generally may determine. The terms of one or more classes or series of preferred stock could dilute the voting power or reduce the value of our common stock. For example, we could grant holders of preferred stock the right to elect some number of our directors in all events or on the happening of specified events or the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences we could assign to holders of preferred stock could affect the residual value of the common stock.

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Item 1B. UNRESOLVED STAFF COMMENTS

None

Item 2. PROPERTIES

The following table provides the segment name, location and general use of each of our principal properties at December 31, 2012 that we own or lease.

Business Segment and Location	Principal Use	Owned/Leased (Lease Expiration)
Power Generation
Barberton, Ohio	Manufacturing facility / administrative office	Owned(1)
West Point, Mississippi	Manufacturing facility	Owned(1)
Lancaster, Ohio	Manufacturing facility	Owned(1)
Copley, Ohio	Warehouse / service center	Owned(1)
Cambridge, Ontario, Canada	Manufacturing facility	Owned
Esbjerg, Denmark	Manufacturing facility	Owned(1)
Dumbarton, Scotland	Manufacturing facility	Owned
Straubing, Germany	Manufacturing facility	Leased (2021)
Guadalupe, NL, Mexico	Manufacturing facility	Leased (2024)
Melville, Saskatchewan, Canada	Manufacturing facility	Owned
Jingshan, Hubei, China	Manufacturing facility	Leased (2013)
Nuclear Operations
Lynchburg, Virginia	Manufacturing facility(3)	Owned
Barberton, Ohio	Manufacturing facility	Owned
Euclid, Ohio	Manufacturing facility	Owned / Leased(2)
Mount Vernon, Indiana	Manufacturing facility	Owned
Erwin, Tennessee	Manufacturing facility	Owned
Technical Services
Lynchburg, Virginia	Administrative office	Leased (2013)
Nuclear Energy
Charlotte, North Carolina	Administrative office	Leased (2019)
Lynchburg, Virginia	Engineering office	Leased (2013)
Cambridge, Ontario, Canada	Manufacturing facility	Owned
Corporate
Charlotte, North Carolina	Administrative office	Leased (2018)

(1) These properties are encumbered by liens under existing credit facilities.

(2) We acquired the Euclid facilities through a bond/lease transaction facilitated by the Cleveland Cuyahoga County Port Authority (the “Port”), whereby we acquired a ground parcel and the Port issued bonds, the proceeds of which were used to acquire, improve and equip the facilities, including the acquisition of the larger facility and a 40-year prepaid ground lease for the smaller facility. We are leasing the facilities from the Port with an expiration date of 2014 but subject to certain extension options.

(3) The Lynchburg, Virginia facility is our Nuclear Operations segment’s primary manufacturing plant and is the nation’s largest commercial high-enriched uranium processing facility. The site is the recipient of the highest rating given by the NRC for license performance. The performance review determines the safe and secure conduct of operations of the facility. The site is also the largest commercial International Atomic Energy Agency-certified facility in the U.S.

We also own or lease a number of sales, administrative and field construction offices, warehouses and equipment maintenance centers strategically located throughout the world. We consider each of our significant properties to be suitable and adequate for its intended use.

For further details regarding our properties, see Item 1, “Business.”

Item 3. LEGAL PROCEEDINGS

The information set forth under the heading “Investigations and Litigation” in Note 10 to our consolidated and combined financial statements included in this report is incorporated by reference into this Item 3.

Item 4. MINE SAFETY DISCLOSURES

We own an interest in and manage and operate Ebensburg Power Company, an independent power company that produces alternative electrical energy. Through one of our subsidiaries, Revloc Reclamation Service, Inc.,

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Ebensburg Power Company operates multiple coal refuse sites in Western Pennsylvania (collectively, the “Revloc Sites”). At the Revloc Sites, Ebensburg Power Company utilizes coal refuse from abandoned surface mine lands to produce energy. Beyond converting the coal refuse to energy, Ebensburg Power Company is also taking steps to reclaim the former surface mine lands to make the land and streams more attractive for wildlife and human uses.

The Revloc Sites are subject to regulation by the federal Mine Safety and Health Administration under the Federal Mine Safety and Health Act of 1977. Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and this Item is included in exhibit 95 to this annual report on Form 10-K.

PART II

Item 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

Our common stock is traded on the New York Stock Exchange under the symbol BWC.

High and low common stock prices by quarter in the years ended December 31, 2012 and 2011 were as follows:

YEAR ENDED DECEMBER 31, 2012

	SALES PRICE
QUARTER ENDED	HIGH		LOW
March 31, 2012	$	27.93	$	23.30
June 30, 2012	$	26.24	$	22.86
September 30, 2012	$	27.00	$	23.86
December 31, 2012	$	26.87	$	22.72
YEAR ENDED DECEMBER 31, 2011
	SALES PRICE
QUARTER ENDED	HIGH		LOW
March 31, 2011	$	36.02	$	25.60
June 30, 2011	$	34.09	$	26.23
September 30, 2011	$	27.99	$	18.05
December 31, 2011	$	24.99	$	18.91

On November 5, 2012, our board of directors approved an annual cash dividend, payable quarterly, of $0.32 per share. On the same date, our board of directors declared a dividend of $0.08 per share payable on December 17, 2012 to shareholders of record on November 19, 2012. Cash dividends paid in the fourth quarter of 2012 totaled $9.5 million. Our ability to pay dividends may be limited by certain restrictions in our credit agreement. Our Board of Directors will continue to evaluate our cash dividend policy from time to time. On February 8, 2013, our board of directors declared a dividend of $0.08 per share payable on March 12, 2013 to shareholders of record on February 19, 2013.

As of January 31, 2013, there were approximately 2,480 record holders of our common stock.

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The following table provides information on our equity compensation plans as of December 31, 2012:

Equity Compensation Plan Information

Plan Category	Number of securities to be issued upon exercise of outstanding options and rights		Weighted-average exercise price of outstanding options and rights		Number of securities remaining available for future issuance
Equity compensation plans approved by security holders		1,431,676	$	25.65		5,389,515

On November 7, 2012, we announced that our board of directors also authorized us to repurchase an indeterminate number of shares of our common stock at an aggregate value of up to $250 million. We may repurchase shares from time to time during a two-year period in the open market. The following table provides information on our purchases of equity securities during the quarter ended December 31, 2012. Any shares purchased that were not part of a publicly announced plan or program are related to repurchases of common stock pursuant to the provisions of employee benefit plans that permit the repurchase of shares to satisfy statutory tax withholding obligations.

Issuer Purchases of Equity Securities

Period	Total number of shares purchased		Average price paid per share		Total number of shares purchased as part of publicly announced plans or programs		Approximate dollar value of shares that may yet be purchased under the plans or programs (in millions)
November 1, 2012 – November 30, 2012		1,606,982	$	24.03		1,606,100	$	211.4
December 1, 2012 – December 31, 2012		2,302,584	$	25.27		2,302,584	$	153.2
Total		3,909,566	$	24.76		3,908,684

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The following graph provides a comparison of our two-year and five-month cumulative total shareholder return through December 2012 to the return of the S&P 500 and our custom peer group. The following graph shall not be deemed to be “soliciting material” or “filed” with the SEC or be subject to Regulation 14A or 14C (other than as provided in Item 201 of Regulation S-K) or to the liabilities of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), nor shall such information be incorporated by reference into any future filing under the Securities Act of 1933, as amended, or the Exchange Act, except to the extent that B&W specifically incorporates it by reference into such filing.

(1) Assumes initial investment of $100 on July 31, 2010.

The peer group used for the two-year and five-month comparison is comprised of the following companies:

• AECOM Technology Corporation

• Chicago Bridge & Iron Company

• Curtiss-Wright Corporation

• Emcor Group, Inc.

• Fluor Corporation

• Foster Wheeler AG

• Jacobs Engineering Group, Inc.

• KBR, Inc.

• MasTec, Inc.

• Quanta Services, Inc.

• Shaw Group, Inc.

• Tetra Tech, Inc.

• URS Corporation

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Item 6. SELECTED FINANCIAL DATA

	For the Years Ended
	2012		2011		2010		2009		2008
	(In thousands, except for per share amounts)
Revenues	$	3,291,359	$	2,952,040	$	2,688,811	$	2,854,632	$	3,398,574
Income (Loss) before Provision for Income Taxes	$	319,418	$	94,498	$	220,208	$	272,154	$	(53,257	)
Net Income Attributable to The Babcock & Wilcox Company	$	227,695	$	78,319	$	139,939	$	171,522	$	16,415
Basic Earnings per Common Share(1):
Net Income Attributable to The Babcock & Wilcox Company	$	1.92	$	0.67	$	1.20	$	1.48	$	0.14
Diluted Earnings per Common Share(1):
Net Income Attributable to The Babcock & Wilcox Company	$	1.91	$	0.66	$	1.19	$	1.46	$	0.14
Cash Dividends Per Common Share	$	0.08		—		—		—		—
Total Assets	$	2,840,355	$	2,789,111	$	2,500,510	$	2,603,859	$	2,506,841
Current Maturities of Long-Term Debt	$	4,062	$	4,653	$	4,790	$	6,432	$	9,021
Long-Term Debt	$	430	$	633	$	855	$	4,222	$	6,109

(1) On July 30, 2010, 116,225,732 shares of our common stock were distributed to MII shareholders to complete our spin-off from MII. For comparative purposes, and to provide a more meaningful calculation of weighted average shares, we have assumed this amount to be outstanding as of the beginning of each period presented prior to our spin-off in our calculation of basic weighted average shares. In addition, for our dilutive weighted average share calculations, we have assumed the dilutive securities outstanding at July 30, 2010 were also outstanding at each of the periods presented prior to our spin-off.

In the fourth quarter of 2012, we elected to change our accounting method for recognizing actuarial gains and losses for our pension and other postretirement benefit plans. Under our new accounting method, we will immediately recognize actuarial gains and losses into earnings in the fourth quarter each year as a component of net periodic benefit cost. This change has been reported through retrospective application of the new accounting method to all periods presented. See Note 6 to our consolidated and combined financial statements included in this report for information on our pension and postretirement benefit plans and Note 20 for disclosures relating to the effect of this change in our accounting method. Also in 2012 we entered into an agreement with the customer of a Nuclear Energy project to settle contract claims resulting in recognition of revenues totaling approximately $18.4 million. In addition, we recorded an impairment totaling $27.0 million associated with our investment in USEC.

In the year ended December 31, 2011, we recorded additional costs totaling approximately $61.8 million ($50.7 million in our Nuclear Energy segment and $11.1 in our Nuclear Operations segment) to complete certain projects attributable to changes in estimate due to productivity and scheduling issues. In addition, we recognized a gain totaling approximately $10.9 million attributable to a settlement with the sellers of Nuclear Fuel Services, Inc. (“NFS”) related to conditions in existence at the acquisition date.

Our historical combined financial information prior to July 2010 reflects our performance as a subsidiary of MII and may not provide a useful indicator of future performance.

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Item 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Statements we make in the following discussion, which express a belief, expectation or intention, as well as those that are not historical fact, are forward-looking statements that are subject to risks, uncertainties and assumptions. Our actual results, performance or achievements, or industry results, could differ materially from those we express in the following discussion as a result of a variety of factors, including the risks and uncertainties we have referred to under the headings “Cautionary Statement Concerning Forward-Looking Statements” and “Risk Factors” in Items 1 and 1A of Part I of this report.

GENERAL

In general, we operate in capital-intensive industries and rely on large contracts for a substantial amount of our revenues. We are currently exploring growth strategies across our segments through acquisitions to expand and complement our existing businesses. As we pursue these opportunities, we expect they would be funded by cash on hand, external financing, including debt, equity or some combination thereof.

We operate in four business segments: Power Generation, Nuclear Operations, Technical Services and Nuclear Energy. We were a wholly owned subsidiary of MII until July 30, 2010, when MII distributed 100% of our outstanding common stock to the MII shareholders. On and prior to July 30, 2010, our financial position, operating results and cash flows consisted of The Babcock & Wilcox Operations of MII, which represented a combined reporting entity comprised of the assets and liabilities involved in managing and operating the Power Generation Systems and Government Operations segments of MII in addition to two captive insurance companies which have been combined and contributed to B&W in conjunction with the spin-off of B&W by MII.

On July 2, 2010, MII’s Board of Directors approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of MII common stock. The distribution of B&W common stock was made on July 30, 2010, and consisted of one share of B&W common stock for every two shares of MII common stock to holders of MII common stock as of 5:00 p.m. New York City time on the record date, July 9, 2010. Cash was paid in lieu of any fractional shares of our common stock. As a result of the spin-off, we became a separate publicly traded company, and MII did not retain any ownership interest in us.

Outlook

Power Generation

We expect the backlog of our Power Generation segment of approximately $2.5 billion at December 31, 2012 to produce revenues of approximately $1.2 billion in 2013, not including any change orders or new contracts that may be awarded during the year. Through this segment, we are actively bidding on and, in some cases, beginning preliminary work on projects that we expect will be awarded to us in 2013 subject to successful contract negotiations. These projects are not currently reflected in backlog.

Our Power Generation segment’s overall activity depends mainly on the capital expenditures of electric power generating companies and other steam-using industries. This segment’s products and services are capital intensive and also dependent on expenditures by original equipment manufacturers. As such, customer demand is heavily affected by the variations in customers’ business cycles, costs of fuel and by the overall economies of the countries in which they operate.

The Environmental Protection Agency (“EPA”) issued proposed final environmental regulations concerning Mercury and Air Toxics Standards (“MATS”) and rules concerning implementation of the Cross State Air Pollution Rule (“CSAPR”) in 2011. On December 30, 2011 the Federal Court of Appeals for the DC Circuit (the “Court”) stayed the CSAPR rules and reinstated EPA regulations from 2005. Oral arguments were held in April 2012. In August 2012, the Court ruled CSAPR, which set stricter limits on sulfur dioxide and nitrogen oxide emissions from power plants in 28 states, violated the Clean Air Act. The ruling leaves CSAPR’s predecessor, the Clean Air Interstate Rule, in place. In October 2012, the EPA appealed the Court’s decision. We believe it could take years for any regulatory response to develop in response to the Court’s ruling.

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Uncertainty concerning environmental final rules and regulations could impact our Power Generation segment. For example, instead of adding environmental equipment, some of our customers may decide to close down their least efficient coal-fired boilers. Future decisions to retire boilers would impact our business in a variety of ways, including the servicing and retrofitting of operating power plants. The need to replace retired generating capacity with cleaner technologies would also create business opportunities for us. To generate energy while minimizing the emission of greenhouse gasses, we are actively researching and developing a range of products, including:

• non-carbon technologies, such as nuclear power plants and solar receivers for concentrating solar power plants;

• low-carbon technologies that enable clean use of fossil fuels, such as oxy-fuel combustion and regenerable solvent absorption technologies to scrub carbon dioxide from exhaust gases; and

• carbon-neutral technologies, such as biomass-fueled boilers and gasifiers, which use a renewable resource where the growing biomass re-absorbs the carbon dioxide emitted during energy production.

Changes and the uncertainties described above regarding the regulatory landscape, low natural gas prices and continued uncertainty in the economy have dampened somewhat the expected rate of growth of our environmental business within this segment. Utilities continue to operate coal-fired plants that require the environmental equipment and services that our Power Generation segment provides. However, we now expect that the timeframe over which such projects will be spread will be longer than our original timeframe of three to four years. We now expect the current environmental cycle to expand to a potentially six- or seven-year period, during which we anticipate a more competitive landscape in the near to medium term.

Nuclear Operations

We expect the backlog of our Nuclear Operations segment of approximately $3.0 billion at December 31, 2012 to produce revenues of approximately $1.1 billion in 2013, not including any change orders or new contracts that may be awarded during the year.

The revenues of our Nuclear Operations segment are largely a function of defense spending by the U.S. Government. As a supplier of major nuclear components for certain U.S. Government programs, we are a significant participant in the defense industry. In August 2011, Congress enacted the Budget Control Act of 2011, which committed the U.S. Government to significantly reducing the federal deficit over ten years. The Budget Control Act will likely constrain discretionary spending by the federal government for a number of years as it capped discretionary spending through 2021. It also established a Joint Committee of Congress to identify an additional $1.2 to $1.5 trillion in deficit reductions by November 23, 2011. The Joint Committee was unable to meet this deadline, triggering a provision, referred to as “sequestration”, that calls for substantial automatic spending cuts split between defense and non-defense programs scheduled to start in March 2013 and continue over a nine-year period. Federal government spending reductions, including through sequestration, could adversely impact U.S. Government programs for which we provide products or services. There is currently no official planning guidance regarding how sequestration would be implemented, if it were to go into effect. As members of Congress and the Administration continue to discuss various options to prevent or defer sequestration, we cannot predict whether any such efforts will succeed. Additionally, while we believe many of our programs are well aligned with national defense and other strategic priorities, and we supply high-end equipment for submarines and aircraft carriers for the U.S. Navy, the outcome of efforts underway regarding sequestration is uncertain and it is possible that spending cuts may be applied to U.S. Government programs across the board, regardless of how programs align with those priorities. There are many variables in how the Budget Control Act could be implemented that will determine its specific impact; however, reductions in federal government spending and sequestration, as currently provided for under the Budget Control Act, could have a material adverse impact on the operating results and cash flows of our Nuclear Operations and Technical Services segments.

Technical Services

A significant portion of this segment’s operations are conducted through joint ventures which typically earn fees and we account for them following the equity method of accounting. See Note 3 to our consolidated and combined financial statements included in this report for financial information on our equity method investments. As a result, this segment reports minimal backlog and revenues.

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With our specialized capabilities of full life-cycle management of special nuclear materials, facilities and technologies, our Technical Services segment is well-positioned to continue to participate in the continuing cleanup, operation and management of the nuclear sites and weapons complexes maintained by the DOE.

Contracts for two projects under B&W led management teams, Y-12 and Pantex, ended in 2010 but were extended while the National Nuclear Security Administration (“NNSA”) conducted a contract re-compete process. In addition, the NNSA determined it would be advantageous to combine the management of Y-12 and Pantex into a single management contract. Proposals were submitted to the NNSA in March of 2012. In late July 2012, the Y-12 National Security Complex in Oak Ridge, Tennessee experienced a security breach. Nuclear operations at the site were temporarily ceased for approximately two weeks in early August 2012. All operations have now resumed. The Y-12 security force had been managed by another DOE prime contractor at the time of the incident. The security contract was assigned to our joint venture by the NNSA following the security breach. The contractor responsible for managing the security force at the time of the security breach was terminated and our joint venture took direct responsibility for security at the Y-12 National Security Complex. Following the security breach, a number of immediate changes and security enhancements were instituted, including the removal and replacement of key B&W leadership personnel, restoration of critical security system elements to service and refining and recalibrating of alarm system components to enhance reliability. The security breach adversely affected the fees earned in 2012 by our joint venture that manages and operates the site. After the security breach, the NNSA revised the request for proposal to include the security work scope into the new management contract. Bidders, including the B&W led joint venture, revised proposals in September of 2012. On January 8, 2013, we were notified that our joint venture was not selected to lead the NNSA’s combined Management and Operating (“M&O”) contract for the Y-12 National Security Complex and Pantex Plant. On January 18, 2013, our joint venture, NP2, filed a protest against NNSA’s award of the M&O contract. We will continue to manage both facilities during the protest period. Once the protest has been resolved we will manage both facilities through the transition process, which is expected to take approximately four months once the transition is initiated.

This segment produced $59.7 million of operating income in 2012, a 15% decrease from 2011. We expect operating income attributable to this segment to be lower in 2013 based on the new ownership fee structure for the combined Y-12/Pantex contract, or the eventual loss of the contract resulting from an unsuccessful protest.

Nuclear Energy

We expect the backlog of our Nuclear Energy segment of approximately $278 million at December 31, 2012 to produce revenues of approximately $180 million in 2013, not including any change orders or new contracts that may be awarded during the year.

During 2012, this segment entered into an agreement with Energy Northwest to settle contract claims related to a project for the removal and replacement of the main plant condenser and related parts at Energy Northwest’s Columbia Generating Station, resulting in the recognition of revenues totaling approximately $18.4 million.

We expect to continue our development of the B&W mPower™ reactor. The development, general and administrative and capital costs to develop and commercialize this technology will require a substantial amount of investment over a period of years, and the funding requirements may vary significantly from period to period. We intend to continue with our plan to seek third party funding and/or participation to pursue the development and commercialization of this technology, including potential funding from the DOE in the form of grants subject to successful negotiations concerning terms and conditions. We expect our spending on development of the B&W mPower™ reactor to be consistent in 2013 compared to 2012 levels, excluding any additional third party funding or grants.

In November 2012, our Nuclear Energy segment was selected as the winner of the DOE’s competitively bid Small Modular Reactor (“SMR”) Licensing Technical Support Program, and will receive funding that will support accelerated development of its B&W mPower™ SMR technology.

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CRITICAL ACCOUNTING POLICIES AND ESTIMATES

Our financial statements and accompanying notes are prepared in accordance with accounting principles generally accepted in the United States. Preparing financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses. These estimates and assumptions are affected by management’s application of accounting policies. We believe the following are our most critical accounting policies that we apply in the preparation of our financial statements. These policies require our most difficult, subjective and complex judgments, often as a result of the need to make estimates of matters that are inherently uncertain.

Contracts and Revenue Recognition. We determine the appropriate accounting method for each of our long-term contracts before work on the project begins. We generally recognize contract revenues and related costs on a percentage-of-completion method for individual contracts or combinations of contracts under the guidelines of FASB Topic Revenue Recognition. The use of this method is based on our experience and history of being able to prepare reasonably dependable estimates of the cost to complete our projects. Under this method, we recognize estimated contract revenue and resulting income based on costs incurred to date as a percentage of total estimated costs. Certain costs may be excluded from the cost-to-cost method of measuring progress, such as significant costs for materials and major third-party subcontractors, if it appears that such exclusion would result in a more meaningful measurement of actual contract progress and resulting periodic allocation of income. Total estimated costs, and resulting contract income, are affected by changes in the expected cost of materials and labor, productivity, scheduling and other factors. Additionally, external factors such as weather, customer requirements and other factors outside of our control may affect the progress and estimated cost of a project’s completion and, therefore, the timing of revenue and income recognition. We routinely review estimates related to our contracts, and revisions to profitability are reflected in the quarterly and annual earnings we report. In the years ended December 31, 2012, 2011 and 2010, we recognized net favorable changes in estimate related to long-term contracts accounted for on the percentage-of-completion basis that increased operating income by approximately $93.1 million, $33.1 million and $112.7 million respectively. The 2012 amount includes approximately $16.9 million of contract losses, net of claims, based on our estimate of costs to complete a project in our Power Generation segment. The 2011 amount includes approximately $61.8 million ($50.7 million in our Nuclear Energy segment and $11.1 in our Nuclear Operations segment) to complete certain projects attributable to unfavorable changes in estimate due to productivity and scheduling issues. The projects in 2011 are now complete.

For contracts as to which we are unable to estimate the final profitability except to assure that no loss will ultimately be incurred, we recognize equal amounts of revenue and cost until the final results can be estimated more precisely. For these deferred profit recognition contracts, we recognize revenue and cost equally and only recognize gross margin when probable and reasonably estimable, which we generally determine to be when the contract is approximately 70% complete. We treat long-term construction contracts that contain such a level of risk and uncertainty that estimation of the final outcome is impractical except to assure that no loss will be incurred as deferred profit recognition contracts.

Fixed-price contracts are required to be accounted for under the completed-contract method if we are unable to reasonably forecast cost to complete at start-up. For example, if we have no experience in performing the type of work on a particular project and were unable to develop reasonably dependable estimates of total costs to complete, we would follow the completed-contract method of accounting for such projects. Generally, our management’s policy is not to enter into fixed-price contracts without an accurate estimate of cost to complete. However, it is possible that in the time between contract execution and the start of work on a project, we could lose confidence in our ability to forecast cost to complete based on intervening events, including, but not limited to, experience on similar projects, civil unrest, strikes and volatility in our expected costs. In such a situation, we would use the completed-contract method of accounting for that project. We did not enter into any contracts that we have accounted for under the completed-contract method during 2012, 2011 or 2010.

For the majority of parts orders and aftermarket services activities, we recognize revenues as goods are delivered and work is performed.

For all contracts, if a current estimate of total contract cost indicates a loss on a contract, the projected loss is recognized in full when determined.

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Although we continually strive to improve our ability to estimate our contract costs and profitability, adjustments to overall contract costs due to unforeseen events could be significant in future periods. We recognize claims for extra work or for changes in scope of work in contract revenues, to the extent of costs incurred, when we believe collection is probable and can be reasonably estimated. We recognize income from contract change orders or claims when formally agreed with the customer. We regularly assess the collectibility of contract revenues and receivables from customers.

Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and the applicable customer asserts a claim under these provisions. These contracts define the conditions and timing under which our customers may make claims against us for liquidated damages. In the majority of cases in which we have had potential exposure for liquidated damages, such damages ultimately were determined not to be caused by our actions or were not otherwise asserted by our customers. Accordingly, we do not accrue liabilities for liquidated damages unless probable and estimable. As of December 31, 2012, we had not accrued for approximately $6.0 million of potential liquidated damages that are not currently due under the particular contract but which we believe could be asserted based upon our current expectations of the time to complete a certain project in our Power Generation segment. We do not believe any of these potential liquidated damages are probable of being assessed due primarily to their relationship to unforeseen worksite conditions that we believe are the responsibility of our customer. We are in active discussions with our customer on the issues giving rise to delays in this project, and we believe we will be successful in obtaining schedule extensions that should resolve the potential for liquidated damages liability. However, we may not achieve relief on some or all of the issues.

Property, Plant and Equipment. We carry our property, plant and equipment at depreciated cost, reduced by provisions to recognize economic impairment when we determine impairment has occurred. Property, plant and equipment amounts are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset, or asset group, may not be recoverable. An impairment loss would be recognized when the carrying amount of an asset exceeds the estimated undiscounted future cash flows expected to result from the use of the asset and its eventual disposition. The amount of the impairment loss to be recorded is calculated by the excess of the assets carrying value over its fair value. Fair value is generally determined using a discounted cash flow analysis. Our estimates of cash flow may differ from actual cash flow due to, among other things, technological changes, economic conditions or changes in operating performance. Any changes in such factors may negatively affect our business segments and result in future asset impairments.

We depreciate our property, plant and equipment using the straight-line method, over estimated economic useful lives of eight to 40 years for buildings and two to 28 years for machinery and equipment. We expense the costs of maintenance, repairs and renewals, which do not materially prolong the useful life of an asset, as we incur them.

Investments in Unconsolidated Affiliates. We use the equity method of accounting for affiliates in which our investment ownership ranges from 20% to 50%, unless significant economic or governance considerations indicate that we are unable to exert significant influence, in which case the cost method is used. The equity method is also used for affiliates in which our investment ownership is greater than 50% but we do not have a controlling interest. Currently, all of our material investments in affiliates that are not included in our consolidated results are recorded using the equity method. Affiliates in which our investment ownership is less than 20% and where we are unable to exert significant influence are carried at cost.

Self-Insurance. We have a wholly owned insurance subsidiary that provides employer’s liability, general and automotive liability and workers’ compensation insurance and, from time to time, builder’s risk insurance within certain limits to our companies. We may also have business reasons in the future to have our insurance subsidiary accept other risks that we cannot or do not wish to transfer to outside insurance companies. When estimating our self-insurance liabilities, we consider a number of factors, including historical claims experience and trend lines, projected growth patterns, inflation and exposure forecasts. The assumptions we make with respect to each of these factors represent our judgment as to the most probable cumulative impact of each factor on our future obligations. Our calculation of self-insurance liabilities requires us to apply judgment to estimate the ultimate cost to settle reported claims and claims incurred but not yet reported as of the balance sheet date. We engage the services of an actuarial firm to assist us in the calculation of our liabilities for self-insurance. While the actual outcome of insured claims could differ significantly from estimated amounts, these loss estimates and accruals recorded in our financial statements for claims have historically been reasonable in light of the actual amount of claims paid. Provisions for

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exposure to self-insurance claims and the related payments of claims have historically not had a material adverse impact on our consolidated financial position, results of operations and cash flows, and we do not expect these provisions to have a material impact on our self-insurance programs in the future.

Pension Plans and Postretirement Benefits. We estimate income or expense related to our pension and postretirement benefit plans based on actuarial assumptions, including assumptions regarding discount rates and expected returns on plan assets. We determine our discount rate based on a review of published financial data and discussions with our actuary regarding rates of return on high-quality, fixed-income investments currently available and expected to be available during the period to maturity of our pension obligations. Based on historical data and discussions with our actuary, we determine our expected return on plan assets based on the expected long-term rate of return on our plan assets and the market-related value of our plan assets. Our pension plan assets can include assets that are difficult to value. Changes in these assumptions can result in significant changes in our estimated pension income or expense and our consolidated financial condition. We revise our assumptions on an annual basis based upon changes in current interest rates, return on plan assets and the underlying demographics of our workforce. These assumptions are reasonably likely to change in future periods and may have a material impact on future earnings.

In the fourth quarter of 2012, we elected to change our accounting method for recognizing actuarial gains and losses for our pension and other postretirement benefit plans. Historically, these gains and losses were recognized as a component of accumulated other comprehensive income on our consolidated balance sheets and we amortized these actuarial gains and losses into earnings over the average remaining service period of our Canadian plans to the extent such gains and losses exceeded a corridor and for our domestic plans we used an amortization method over the average remaining service period without the use of a corridor. Under our new accounting method, we will immediately recognize actuarial gains and losses into earnings in the fourth quarter each year as a component of net periodic benefit cost. This change in accounting will have no impact on the funding of our pension and other postretirement benefit plans or the Company’s cash flow. This change has been reported through retrospective application of the new accounting method to all periods presented. See Note 6 to our consolidated and combined financial statements included in this report for information on our pension and postretirement benefit plans and Note 20 for disclosures relating to the effect of this change in our accounting method.

Loss Contingencies. We estimate liabilities for loss contingencies when it is probable that a liability has been incurred and the amount of loss is reasonably estimable. We provide disclosure when there is a reasonable possibility that the ultimate loss will exceed the recorded provision or if such probable loss is not reasonably estimable. We are currently involved in some significant litigation, as discussed in Note 10 to our consolidated and combined financial statements included in this report. We have accrued our estimates of the probable losses associated with these matters. However, our losses are typically resolved over long periods of time and are often difficult to estimate due to the possibility of multiple actions by third parties. Therefore, it is possible that future earnings could be affected by changes in our estimates related to these matters.

Goodwill. In accordance with FASB Topic Intangibles – Goodwill and Other, we perform periodic testing of goodwill for impairment. We utilize a two-step impairment test to identify potential goodwill impairment and measure the amount of a goodwill impairment loss. The first step of the test compares the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying amount of a reporting unit exceeds its fair value, the second step of the goodwill impairment test is performed to measure the amount of the impairment loss, if any. The second step compares the implied fair value of the reporting unit’s goodwill with the carrying amount of that goodwill. Each year, we evaluate goodwill at each reporting unit to assess recoverability and impairments, if any, are recognized in earnings. An impairment loss would be recognized in an amount equal to the excess of the carrying amount of the goodwill over the implied fair value of the goodwill. We determined that both the income and market valuation approaches provide inputs into the estimate of the fair value of our reporting units, which would be considered by market participants. Under the income valuation approach, we employ a discounted cash flow model to estimate the fair value of each reporting unit. This model requires the use of significant estimates and assumptions regarding future revenues, costs, margins, capital expenditures, changes in working capital, terminal year growth rate and cost of capital. Our cash flow models are based on our forecasted results for the applicable reporting units. Actual results could differ from our projections. Under the market valuation approach, we employ the guideline publicly traded company method, which indicates the fair value of the equity of each reporting unit by comparing it to publicly traded companies in similar lines of business. After identifying and selecting guideline companies, we analyze their business and financial profiles for relative similarity. Factors such as size, growth, risk and profitability are analyzed and compared to each of our reporting units. We have completed our annual review of goodwill for each of our reporting units for the year ended December 31, 2012, which indicated that we had no impairment of goodwill. The fair value of our reporting units was substantially in excess of carrying value.

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Asset Retirement Obligations and Environmental Clean-up Costs. We accrue for future decommissioning of our nuclear facilities that will permit the release of these facilities to unrestricted use at the end of each facility’s life, which is a requirement of our licenses from the NRC. In accordance with the FASB Topic Asset Retirement and Environmental Obligations, we record the fair value of a liability for an asset retirement obligation in the period in which it is incurred. In estimating fair value, we use present value of cash flows expected to be incurred in settling our obligations. To the extent possible, we perform a marketplace assessment of the cost and timing of performing the retirement activities. We apply a credit-adjusted risk-free interest rate to our expected cash flows in our determination of fair value. When we initially record such a liability, we capitalize a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of a liability, we will settle the obligation for its recorded amount or incur a gain or loss. This topic applies to environmental liabilities associated with assets that we currently operate and are obligated to remove from service. For environmental liabilities associated with assets that we no longer operate, we have accrued amounts based on the estimated costs of clean-up activities, net of the anticipated effect of any applicable cost-sharing arrangements. We adjust the estimated costs as further information develops or circumstances change. An exception to this accounting treatment relates to the work we perform for two facilities for which the U.S. Government is obligated to pay substantially all the decommissioning costs.

Income Taxes. Income tax expense for federal, foreign, state and local income taxes are calculated on pre-tax income based on current tax law and include the cumulative effect of any changes in tax rates from those used previously in determining deferred tax assets and liabilities. We record a valuation allowance to reduce our deferred tax assets to the amount that is more likely than not to be realized. We assess deferred taxes and the adequacy of the valuation allowance on a quarterly basis. In the ordinary course of business there is inherent uncertainty in quantifying our income tax positions. We assess our income tax positions and record tax benefits for all years subject to examination based upon management’s evaluation of the facts, circumstances, and information available at the reporting date. For those tax positions where it is more-likely-than-not that a tax benefit will be sustained, we have recorded the largest amount of tax benefit with a greater than 50% likelihood of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. For those income tax positions where it is not more-likely-than-not that a tax benefit will be sustained, no tax benefit has been recognized in the financial statements. We record interest and penalties (net of any applicable tax benefit) related to income taxes as a component of provision for income taxes on our Statements of Income.

Warranty. We account for warranty costs to satisfy contractual warranty requirements as an accrued estimated expense included in cost of operations on our consolidated and combined statements of income recognized in conjunction with the associated revenue on the related contracts. In addition, we make specific provisions or reductions where we expect the actual warranty costs to significantly differ from the accrued estimates. Factors that impact our estimate of warranty costs include prior history of warranty claims and our estimates of future costs of materials and labor. Our future warranty provisions may vary from what we have experienced in the past.

Stock-Based Compensation. We account for stock-based compensation in accordance with FASB Topic Compensation – Stock Compensation. Under the fair value recognition provisions of this statement, the cost of employee services received in exchange for an award of equity instruments is measured at the grant date based on the fair value of the award. Stock-based compensation expense is recognized on a straight-line basis over the requisite service periods of the awards, which is generally equivalent to the vesting term. We use a Black-Scholes model to determine the fair value of certain share-based awards, such as stock options and stock appreciation rights. The determination of the fair value of a share-based payment award using an option-pricing model requires the input of highly subjective assumptions, such as the expected life of the award and stock price volatility. For liability-classified awards, such as cash-settled restricted stock units and performance units, fair values are determined at grant date using the closing price of our common stock and are remeasured at the end of each reporting period through the date of settlement.

Business Combinations. We account for acquisitions in accordance with FASB Topic Business Combinations. This topic broadens the fair value measurements and recognition of assets acquired, liabilities assumed and interests transferred as a result of business combinations. It also provides disclosure requirements to assist users of the financial statements in evaluating the nature and financial effects of business combinations.

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For further discussion of recently adopted accounting standards, see Note 1 to our consolidated and combined financial statements included in this report.

YEAR ENDED DECEMBER 31, 2012 COMPARED TO YEAR ENDED DECEMBER 31, 2011

The Babcock & Wilcox Company

Consolidated revenues increased 11.5%, or $339.3 million, to $3.29 billion in the year ended December 31, 2012 compared to $2.95 billion in 2011. Our Power Generation segment revenues increased $244.5 million, or 15.9%, primarily attributable to increased revenue in our new build environmental equipment and new build steam generation systems businesses, partially offset by decreases in our aftermarket services business. Our Nuclear Operations segment experienced a $54.8 million, or 5.3%, increase in revenues, primarily attributable to increased activity in the manufacturing of nuclear components for U.S. Government programs and increased volume in our naval nuclear fuel and downblending activities. Our Technical Services segment revenues decreased $11.8 million, or 9.9%. In addition, our Nuclear Energy segment revenues increased $4.6 million, or 1.4%.

Consolidated operating income increased $250.9 million to $346.6 million in the year ended December 31, 2012 from $95.7 million in 2011. Operating income includes actuarial gains and losses related to our pension and postretirement plans, which were fourth quarter non-cash losses totaling $31.9 million and $215.4 million in 2012 and 2011, respectively. We experienced increased operating income in our Nuclear Operations segment associated with the revenue growth discussed above totaling $31.9 million. Operating income for our Nuclear Energy segment increased $54.0 million, primarily attributable to project costs to complete the condenser replacement project at Columbia Generating Station recognized during 2011 that did not reoccur in 2012. These increases were partially offset by decreased operating income in our Technical Services segment totaling $10.2 million, primarily due to reduced award fees earned in 2012 and increased corporate expenses which totaled $7.6 million. Operating income in our Power Generation segment was relatively unchanged in 2012. See Note 20 to our consolidated and combined financial statements included in this report for additional information concerning the change in accounting method for our pension and post-retirement plans.

Power Generation

Revenues increased 15.9%, or $244.5 million, to $1,786.0 million in the year ended December 31, 2012, compared to $1,541.5 million in 2011, primarily attributable to a $210.7 million increase in our new build environmental equipment business and a $94.4 million increase in our new build steam generation systems business. In our new build environmental equipment business, the increase in revenues was principally driven by ongoing engineering, procurement and construction activities on projects as a result of new environmental rules and regulations. In our new build steam generation systems business, the main driver for this increase in revenues was a significant increase in activity on waste-to-energy and biomass boiler projects. These increases were partially offset by lower revenues of $53.1 million in our aftermarket services business primarily due to lower construction activities on boiler retrofit service projects and boiler replacement parts sales to existing power plants largely as a result of reduced demand from coal fired power plants due to lower natural gas prices. The aftermarket services business did however experience an increase in aftermarket environmental parts, services and construction activities as customers invested to keep their existing environmental equipment in compliance with new environmental rules and regulations.

Operating income was relatively unchanged at $183.4 million in the year ended December 31, 2012 compared to $184.0 million in 2011. The increases in revenues discussed above were partially offset by more competitive profit margins from the early market cycle of environmental projects along with a lower level of project improvements on project closeouts than experienced in the prior year period. We also experienced a decrease in equity in income of investees totaling $8.4 million, primarily attributable to lower production and project activities at our joint venture in China. In addition, we incurred increased research and development expenses totaling $1.6 million for the period in 2012 as compared to the same period in the prior year. Further, we experienced impairment charges totaling $3.2 million in 2012 and gains on asset disposals totaling $3.5 million in 2011.

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Nuclear Operations

Revenues increased 5.3%, or $54.8 million, to $1,098.0 million in the year ended December 31, 2012 compared to $1,043.2 million in the corresponding period of 2011, primarily attributable to increased activity in the manufacturing of nuclear components for U.S. Government programs totaling $36.2 million and increased volume in our naval nuclear fuel and downblending activities totaling $18.6 million as compared to the corresponding period of 2011.

Operating income increased $31.9 million to $226.3 million in the year ended December 31, 2012 compared to $194.4 million in the corresponding period in 2011, primarily due to improved contract performance for the manufacturing of nuclear components for U.S. Government programs totaling $23.4 million. Our naval nuclear fuel and downblending operating income also increased $8.5 million compared to 2011. Included in operating income for 2011 is a $10.9 million gain resulting from a favorable settlement with the previous owner of NFS. Contract performance associated with naval nuclear fuel and downblending activities improved $19.4 million compared to 2011.

Technical Services

Revenues decreased 9.9%, or $11.8 million, to $107.9 million in the year ended December 31, 2012 compared to $119.7 million for the corresponding period of 2011. These decreases are primarily attributable to a decrease in our specialty manufacturing work scope associated with the American Centrifuge program totaling $8.9 million and a decrease in our international contract support services associated with the Fukushima event totaling $3.5 million, partially offset by an increase in environmental remediation services.

Operating income decreased $10.2 million to $59.7 million in the year ended December 31, 2012 compared to $69.9 million in the corresponding period of 2011. This decrease is principally due to decreased award fees earned on our NNSA management contracts totaling $7.9 million, primarily attributable to our Oak Ridge, Tennessee and Los Alamos, New Mexico sites. We also experienced a decrease in operating income totaling $3.8 million associated with the decreased revenues from the American Centrifuge program discussed above and increased selling, general and administrative expenses totaling $3.3 million associated with higher bid and proposal activity. These amounts were offset by increased environmental remediation services income totaling $1.4 million and lower research and development expenses totaling $1.2 million.

Nuclear Energy

Revenues increased 1.4%, or $4.6 million, to $326.0 million in the year ended December 31, 2012 compared to $321.4 million in the corresponding period of 2011, primarily attributable to increased activity in our nuclear services and nuclear equipment businesses of $18.5 million principally due to timing of customer outage projects and execution of our long-term equipment manufacturing contracts. This revenue increase was partially offset by lower revenue in our nuclear projects business due to the completion of a major project in the prior year. For the year ended December 31, 2012, revenues in our nuclear projects business also included $18.4 million from the May 2012 claims settlement agreement reached with Energy Northwest related to a condenser replacement project at the Columbia Generating Station in 2011.

Operating income increased $54.0 million to a loss of $62.9 million in the year ended December 31, 2012 compared to a loss of $116.9 million in the corresponding period of 2011, primarily due to $50.7 million of project costs to complete the condenser replacement project at Columbia Generating Station recognized during the year ended December 31, 2011 and $18.1 million income (net of related expenses) recognized in the year ended December 31, 2012 associated with the May 2012 settlement discussed above. In addition, operating income in our nuclear services and nuclear equipment businesses increased by $3.6 million associated with the increased revenue discussed above. These increases were partially offset by $12.1 million of increased research and development costs related to the continued development of the B&W mPower™ reactor, including a $1.4 million increase in non-cash in-kind research and development services contributed by GmP’s minority partner. In addition, we experienced increases in selling, general and administrative expenses totaling $4.7 million related to the continued expansion of our presence in the commercial nuclear energy industry.

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Corporate

Unallocated corporate expenses increased $7.6 million to $28.0 million in the year ended December 31, 2012, as compared to $20.4 million in 2011, mainly due to higher information technology costs, outside consultant costs and a decrease in operating results in our captive insurance company in 2012 compared to 2011.

Other Income Statement Items

Other income (expense)—net decreased $26.9 million to a loss of $24.9 million in the year ended December 31, 2012, as compared to income of $2.0 million for the corresponding period in 2011, primarily due to the impairment of our USEC investment totaling $27.0 million which we recognized in the three months ended September 30, 2012.

Net Loss (Income) Attributable to Noncontrolling Interest

Net Loss (Income) Attributable to Noncontrolling Interest increased $2.4 million in the year ended December 31, 2012 compared to 2011, primarily attributable to noncontrolling interest recognition of losses incurred in connection with development efforts associated with GmP.

Provision for Income Taxes

For the year ended December 31, 2012, our provision for income taxes increased $78.0 million to $101.9 million, while income before provision for income taxes increased $224.9 million to $319.4 million. Our effective tax rate was approximately 31.9% for 2012, as compared to 25.3% for 2011. The increase in our effective tax rate is primarily attributable to a significant shift in jurisdictional mix of pre-tax earnings in 2012 as compared to 2011, and the temporary expiration in 2012 of the U.S. research & development tax credit, offset in part by a reduction of reserves for uncertain tax positions.

Income before provision for income taxes, provision for income taxes and effective tax rates for our U.S. and non-U.S. jurisdictions were as shown below:

	Income before Provision for Income Taxes				Provision for Income Taxes				Effective Tax Rate
	2012		2011		2012		2011		2012			2011
	(In thousands)				(In thousands)
United States	$	222,840	$	39,417	$	78,868	$	17,172		35.4	%		43.6	%
Non-United States		96,578		55,081		22,993		6,708		23.8	%		12.2	%
Total	$	319,418	$	94,498	$	101,861	$	23,880		31.9	%		25.3	%

We are subject to U.S. federal income tax at a statutory rate of 35% on our U.S. operations plus the applicable state income taxes on our profitable U.S. subsidiaries. Our non-U.S. earnings are subject to tax at various tax rates and under various tax regimes, including deemed profits tax regimes.

The American Taxpayer Relief Act of 2012 was signed into law on January 2, 2013. Some provisions of this law provide for retroactive changes to the 2012 tax year which we did not consider in determining our effective tax rate for 2012. The impact of these retroactive changes will be recorded in the first quarter of 2013.

See Note 4 to our consolidated and combined financial statements included in this report for further information on income taxes.

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YEAR ENDED DECEMBER 31, 2011 COMPARED TO YEAR ENDED DECEMBER 31, 2010

The Babcock & Wilcox Company

Consolidated revenues increased 9.8%, or $263.2 million, to $2.95 billion in the year ended December 31, 2011, compared to $2.69 billion in the year ended December 31, 2010. Our Power Generation segment revenues increased 8.2% in the year ended December 31, 2011, as compared to 2010, primarily attributable to increased revenues in our aftermarket services and new build steam generation systems business, partially offset by lower revenues in our new build environmental equipment business. Our Nuclear Operations segment experienced a 4.7% increase in revenues primarily attributable to increased activity at our NFS subsidiary and increased activity in the manufacturing of nuclear components for certain U.S. Government programs. In addition, our Technical Services segment’s revenues increased 32.8%, primarily attributable to increased work scope on one of our environmental remediation services contracts. Revenues in our Nuclear Energy segment increased 63.7%, primarily attributable to increased activity in our nuclear equipment, nuclear projects and nuclear services businesses.

Consolidated operating income decreased $153.2 million from $248.9 million in 2010 to $95.7 million in 2011. Operating income includes actuarial losses related to our pension and postretirement plans, which were fourth quarter non-cash losses totaling $215.4 million and $91.5 million in 2011 and 2010, respectively. Our Nuclear Energy segment experienced an increase in its operating loss totaling $90.5 million compared to the year ended December 31, 2010, attributable to increased research and development expenses and increased costs to complete a nuclear project contract. Operating income in our Nuclear Operations segment increased $25.8 million in 2011 compared to 2010, and by $22.8 million in our Technical Services segment. In addition, our Power Generation segment experienced an increase in operating income totaling $14.9 million in 2011 while our Unallocated Corporate expenses were higher in 2011 compared to 2010 by $2.4 million.

Power Generation

Revenues increased 8.2%, or $116.9 million, to $1,541.5 million in the year ended December 31, 2011, compared to $1,424.6 million in 2010, primarily attributable to a $30.4 million increase in our new build steam generation systems business, and a $129.1 million increase in our aftermarket services business. In our new build steam generation systems business, the main driver for this increase in revenues was a significant increase in activity on waste to energy and biomass boiler projects partially offset by decreased activity on utility and industrial boiler projects. In our aftermarket services business, the main drivers for this increase in revenues was an increase in North American construction activity on retrofit service projects, boiler replacement parts, environmental parts and upgrades at various fossil fuel power plants in order to maintain reliability and environmental compliance. These increases were partially offset by decreases in revenues of $41.7 million in our new build environmental equipment business, primarily due to completion of major projects in the corresponding period of 2010, partially offset by increased engineering and design work on recent new orders.

Operating income increased $14.9 million to $184.0 million in the year ended December 31, 2011 compared to $169.1 million in the corresponding period of 2010. This increase is attributable to the net increase in revenues discussed above from our new build steam generation systems business and aftermarket services business partially offset by our lower operating income in our new build environmental equipment business. We also experienced a decrease in our selling, general and administrative expenses totaling approximately $4.4 million in the year ended December 31, 2011 compared to the corresponding period of 2010, primarily due to various cost savings programs that began in 2010, partially offset by higher expenses in support of increased bidding activity on environmental and other new business opportunities. In addition, we experienced a decrease in research and development expenses of $4.3 million in the year ended December 31, 2011 compared to the corresponding period of 2010. We also experienced higher levels of operating income in 2010 attributable to the completion and closeout of several projects. Our equity in income of investees decreased $5.0 million in the year ended December 31, 2011 primarily as a result of higher margins in 2010 attributable to reductions in cost on material purchases experienced in our joint venture in China, and increased spending incurred in 2011 with the start up of our joint venture in India.

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Nuclear Operations

Revenues increased 4.7%, or $47.2 million, to $1,043.2 million in the year ended December 31, 2011 compared to $996.0 million in the corresponding period of 2010, primarily attributable to increased activity at NFS totaling $38.6 million and increased activity in the manufacturing of nuclear components for certain U.S. Government programs totaling $8.6 million. A substantial portion of our NFS operation was temporarily shut down during a large portion of the first six months of 2010 due to safety and compliance issues.

Operating income increased $25.8 million to $194.4 million in the year ended December 31, 2011 from $168.6 million in the corresponding period of 2010. Our manufacturing operations contributed $177.0 million to operating income for the twelve months ended December 31, 2011 resulting in a $5.9 million increase compared to the corresponding period of 2010. In addition, NFS generated operating income of $17.4 million in the twelve months ended December 31, 2011 compared to an operating loss of $2.5 million in 2010. Included in NFS’ operating income for the twelve months ended December 31, 2011 is a $10.9 million gain resulting from a settlement with the previous owner of NFS, and $11.1 million in cost increases on certain downblending contracts due to productivity and processing issues. In addition, in 2010 NFS recorded an $8.7 million gain as a result of a change in estimate of an environmental reserve.

Technical Services

Revenues increased 32.8%, or $29.6 million, to $119.7 million in the year ended December 31, 2011 compared to $90.1 million in the corresponding period of 2010. This increase is primarily attributable to increased work scope on one of our environmental remediation services contracts totaling $10.5 million, new awards for decontamination and decommissioning totaling $4.2 million, support services to Fukushima contracts totaling $2.3 million, and transition and task order support from new awards totaling $9.4 million.

Operating income increased $22.8 million to $69.9 million in the year ended December 31, 2011 compared to $47.1 million in the corresponding period of 2010. This improved performance is primarily attributable to an increase in equity income from investees totaling $9.6 million due to higher fees at our government sites of $1.8 million and three new contract awards totaling $7.8 million. In addition, we experienced increases in operating income attributable to production schedules in specialty manufacturing activities totaling $3.0 million, increased scope on one of our environmental remediation services contracts totaling $2.5 million, and increased fees at a government site in Nevada of $2.2 million. Additionally, we experienced lower research and development expenses of $2.9 million.

Nuclear Energy

Revenues increased 63.7%, or $125.1 million, to $321.4 million in the year ended December 31, 2011 compared to $196.3 million in the corresponding period of 2010, primarily attributable to increased activity in our nuclear equipment, nuclear projects and nuclear services businesses.

Operating income decreased $90.5 million to a loss of $116.9 million in the year ended December 31, 2011 compared to a loss of $26.4 million in the corresponding period of 2010. We experienced $43.5 million of increased research and development costs related to the continued development of the B&W mPower^TM reactor, including $16.6 million of non-cash in-kind research and development services contributed by GmP’s minority partner. We also experienced an increase in our selling, general and administrative expenses totaling $16.1 million as we continue to expand our Nuclear Energy segment and increase our presence in the nuclear energy industry. In addition, we recorded increased project costs to complete a nuclear project contract totaling approximately $50.1 million during the year ended December 31, 2011 attributable to productivity, scheduling, scoping and execution issues. This project is now complete. There are no offsetting claims or equitable adjustments included in these loss provisions. These costs were partially offset by improved margins in our nuclear equipment and nuclear services businesses.

Corporate

Unallocated corporate expenses increased by $2.4 million from $18.0 million in the year ended December 31, 2010 to $20.4 million in 2011, due to higher pension expense, partially offset by lower information technology expenses, reduced legal and other professional service expenses, and improved operating results in our captive insurance company.

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Other Income Statement Items

Interest expense decreased $8.4 million in the year ended December 31, 2011 compared to 2010, primarily due to a decrease in interest expense attributable to intercompany borrowings in 2010 between B&W and MII that were in existence prior to the spin-off.

Other income (expense) – net increased $18.9 million to income of $2.0 million in the year ended December 31, 2011 compared to expense of $16.9 million in 2010, primarily due to foreign currency exchange losses incurred in 2010, and increased dividend income on our USEC investment in 2011 compared to 2010.

Net Loss (Income) Attributable to Noncontrolling Interest

Net Loss (Income) Attributable to Noncontrolling Interest increased $8.0 million in the year ended December 31, 2011 compared to 2010 primarily attributable to noncontrolling interest recognition of losses incurred in connection with development efforts associated with GmP.

Provision for Income Taxes

For the year ended December 31, 2011, our provision for income taxes decreased $56.1 million to $23.9 million, while income before provision for income taxes decreased $125.7 million to $94.5 million. Our effective tax rate was approximately 25.3% for 2011, as compared to 36.3% for 2010. The decrease in our effective tax rate is primarily attributable to a significant shift in the jurisdictional mix of our pre-tax earnings, and settlements with certain tax authorities, offset in part by nondeductible in-kind research and development expenses and increases in our valuation allowance attributable to state income taxes.

Income before provision for income taxes, provision for income taxes and effective tax rates for our U.S. and non-U.S. jurisdictions were as shown below:

	Income before Provision for Income Taxes				Provision for Income Taxes				Effective Tax Rate
	2011		2010		2011		2010		2011			2010
	(In thousands)				(In thousands)
United States	$	39,417	$	174,242	$	17,172	$	70,372		43.6	%		40.4	%
Non-United States		55,081		45,966		6,708		9,633		12.2	%		21.0	%
Total	$	94,498	$	220,208	$	23,880	$	80,005		25.3	%		36.3	%

We are subject to U.S. federal income tax at a statutory rate of 35% on our U.S. operations plus the applicable state income taxes on our profitable U.S. subsidiaries. Our non-U.S. earnings are subject to tax at various tax rates and under various tax regimes, including deemed profits tax regimes.

See Note 4 to our consolidated and combined financial statements included in this report for further information on income taxes.

EFFECTS OF INFLATION AND CHANGING PRICES

Our financial statements are prepared in accordance with generally accepted accounting principles in the United States, using historical U.S. dollar accounting (“historical cost”). Statements based on historical cost, however, do not adequately reflect the cumulative effect of increasing costs and changes in the purchasing power of the U.S. dollar, especially during times of significant and continued inflation.

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In order to minimize the negative impact of inflation on our operations, we attempt to cover the increased cost of anticipated changes in labor, material and service costs, either through an estimate of those changes, which we reflect in the original price, or through price escalation clauses in our contracts. However, there can be no assurance we will be able to cover all changes in cost using this strategy.

LIQUIDITY AND CAPITAL RESOURCES

Our overall liquidity position, which we generally define as our unrestricted cash and investments plus amounts available for borrowings under our credit facility, remained strong in 2012. Our liquidity position at December 31, 2012 increased by approximately $42.2 million to $1,018.5 million from $976.3 million at December 31, 2011, mainly due to factors discussed below, and the changes in our cash flows from operating, investing and financing activities. We experienced net cash generated from operations in each of the years ended December 31, 2012, 2011 and 2010. Typically, the fourth quarter has been the period of highest cash flows from operating activities, primarily attributable to payments received from the U.S. Government on accounts receivable retainages, cash dividends received from our joint ventures and strong working capital performance.

Credit Facility

On June 8, 2012, B&W entered into an Amended and Restated Credit Agreement (the “Credit Agreement”) with a syndicate of lenders and letter of credit issuers, and Bank of America, N.A., as administrative agent, which amends and restates our previous Credit Agreement dated May 3, 2010. The Credit Agreement provides for revolving credit borrowings and issuances of letters of credit in an aggregate outstanding amount of up to $700 million, and is scheduled to mature June 8, 2017. The proceeds of the Credit Agreement are available for working capital needs and other general corporate purposes. The Credit Agreement includes procedures for additional financial institutions to become lenders, or for any existing lender to increase its commitment thereunder, subject to an aggregate maximum of $1.0 billion for all revolving loan and letter of credit commitments.

The Credit Agreement is guaranteed by substantially all of B&W’s wholly owned domestic subsidiaries. Obligations under the Credit Agreement are secured by first-priority liens on certain assets owned by B&W and the guarantors (other than subsidiaries comprising our Nuclear Operations and Technical Services segments). If the corporate family rating of B&W and its subsidiaries from Moody’s is Baa3 or better (with a stable outlook or better), the corporate rating of B&W and its subsidiaries from S&P is BBB- or better (with a stable outlook or better), and other conditions are met, the liens securing obligations under the Credit Agreement will be released, subject to reinstatement upon the terms set forth in the Credit Agreement.

The Credit Agreement requires only interest payments on a periodic basis until maturity. We may prepay all loans under the Credit Agreement at any time without premium or penalty (other than customary LIBOR breakage costs), subject to certain notice requirements.

The Credit Agreement contains financial covenants relating to leverage and interest coverage and includes covenants that restrict, among other things, the level of debt incurrence, liens, investments, acquisitions, asset dispositions, dividends, prepayments of subordinated debt and mergers. At December 31, 2012, we were in compliance with all of the covenants set forth in the Credit Agreement. A comparison of the key financial covenants and current compliance at December 31, 2012 is as follows:

	Required	Actual
	Less than
Maximum leverage ratio	2.75 to 1.0	0.06 to 1.0
	Greater than
Minimum interest coverage ratio	4.0 to 1.0	78.13 to 1.0

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Loans outstanding under the Credit Agreement bear interest at our option at either the Eurocurrency rate plus a margin ranging from 1.25% to 2.25% per year or the base rate (the highest of the Federal Funds rate plus 0.50%, the one month Eurocurrency rate plus 1.0%, or the administrative agent’s prime rate) plus a margin ranging from 0.25% to 1.25% per year. The applicable margin for revolving loans varies depending on the credit ratings of the Credit Agreement. Under the Credit Agreement, we are charged a commitment fee on the unused portions of the Credit Agreement and that fee varies between 0.225% and 0.350% per year depending on the credit ratings of the Credit Agreement. Additionally, we are charged a letter of credit fee of between 1.25% and 2.25% per year with respect to the amount of each financial letter of credit issued under the Credit Agreement and a letter of credit fee of between 0.80% and 1.25% per year with respect to the amount of each performance letter of credit issued under the Credit Agreement, in each case depending on the credit ratings of the Credit Agreement. We also pay customary fronting fees and other fees and expenses in connection with the issuance of letters of credit under the Credit Agreement. In connection with entering into the Credit Agreement, we paid upfront fees to the lenders thereunder, and arrangement and other fees to the arrangers and agents of the Credit Agreement. At December 31, 2012, there were no borrowings outstanding and letters of credit issued under the Credit Agreement totaled $157.9 million, resulting in $542.1 million available for borrowings or to meet letter of credit requirements. The applicable interest rate at December 31, 2012 under this facility was 3.75% per year for revolving loans.

Based on the current credit ratings of the Credit Agreement, the applicable margin for Eurocurrency loans is 1.50%, the applicable margin for base rate loans is 0.50%, the letter of credit fee for financial letters of credit is 1.50%, the letter of credit fee for performance letters of credit is 0.875%, and the commitment fee for unused portions of the Credit Agreement is 0.25%. The Credit Agreement does not have a floor for the base rate or the Eurocurrency rate.

The Credit Agreement generally includes customary events of default for a secured credit facility. If any default occurs under the Credit Agreement, or if we are unable to make any of the representations and warranties in the Credit Agreement, we will be unable to borrow funds or have letters of credit issued under the Credit Agreement.

Other Arrangements

Certain foreign subsidiaries within our Power Generation segment have credit arrangements with various commercial banks and other financial institutions for the issuance of bank guarantees in association with contracting activity. The aggregate value of all such bank guarantees as of December 31, 2012 was $59.4 million.

We have posted surety bonds to support contractual obligations to customers relating to certain projects. We utilize bonding facilities to support such obligations, but the issuance of bonds under those facilities is typically at the surety’s discretion. Although there can be no assurance that we will maintain our surety bonding capacity, we believe our current capacity is more than adequate to support our existing project requirements for the next twelve months. In addition, these bonds generally indemnify customers should we fail to perform our obligations under the applicable contracts. We, and certain of our subsidiaries, have jointly executed general agreements of indemnity in favor of surety underwriters relating to surety bonds those underwriters issue in support of some of our contracting activity. As of December 31, 2012, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $468.6 million.

OTHER

Foreign Operations

Included in our total unrestricted cash and cash equivalents is approximately $172.8 million or 45% related to foreign operations and subsidiaries. In general, these resources are not available to fund our U.S. operations unless the funds are repatriated to the United States, which would expose us to taxes we presently have not accrued in our results of operations. We presently have no plans to repatriate these funds to the U.S. as the liquidity generated by our U.S. operations is sufficient to meet the cash requirements of our U.S. operations.

Cash, Cash Equivalents, Restricted Cash and Investments

In the aggregate, our cash and cash equivalents, restricted cash and cash equivalents and investments decreased by approximately $10.8 million to $540.3 million at December 31, 2012 from $551.1 million at December 31, 2011, primarily due to the items discussed below.

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Our working capital increased by approximately $109.5 million to $441.8 million at December 31, 2012 from $332.3 million at December 31, 2011, attributable to a reduction in total current liabilities in 2012 related to accrued employee benefits, primarily due to lower anticipated fundings to our pension plans in 2013 compared to 2012 attributable to MAP-21 legislation, which reduces required contributions for single-employer pension plans.

Our net cash provided by operating activities was approximately $184.9 million in the year ended December 31, 2012 compared to $173.6 million in the year ended December 31, 2011. This difference was primarily attributable to changes in net contracts in progress and advance billings.

Our net cash used in investing activities decreased by approximately $42.9 million to approximately $111.4 million in the year ended December 31, 2012 from approximately $154.3 million in the year ended December 31, 2011. This decrease in net cash used in investing activities was primarily attributable to a decrease in restricted cash in the current year compared to an increase in the prior year.

Our net cash used in financing activities increased by approximately $115.5 million to cash used in financing activities of $108.0 million in the year ended December 31, 2012 from $7.5 million provided by financing activities in the year ended December 31, 2011. This increase in net cash used in financing activities was primarily attributable to the repurchase of common shares and the payment of dividends in 2012.

At December 31, 2012, we had restricted cash and cash equivalents totaling $63.9 million, $8.0 million of which was held in restricted foreign cash accounts, $2.9 million of which was held for future decommissioning of facilities (which is included in other assets on our consolidated balance sheets), $51.9 million of which was held to meet reinsurance reserve requirements of our captive insurer (in lieu of long-term investments), and $1.1 million of which was held in money market funds maintained by our captive insurer.

At December 31, 2012, we had short-term and long-term investments with a fair value of $92.9 million. Our investment portfolio consists primarily of investments in government obligations and other highly liquid money market instruments.

Our investments are classified as available-for-sale and are carried at fair value with unrealized gains and losses, net of tax, reported as a component of other comprehensive income. Our net unrealized gain/loss on investments is currently in an unrealized gain position totaling approximately $0.6 million at December 31, 2012. At December 31, 2011, we had unrealized gains on our investments totaling approximately $0.2 million. Based on our analysis of these investments, we believe that none of our available-for-sale securities were permanently impaired as of December 31, 2012.

Based on our liquidity position, we believe we have sufficient cash and letter of credit and borrowing capacity to fund our operating requirements for at least the next twelve months.

CONTRACTUAL OBLIGATIONS

Our cash requirements as of December 31, 2012 under current contractual obligations were as follows:

	Total		Less than 1 Year		1-3 Years		3-5 Years		After 5 Years
	(In thousands)
Long-term debt principal (a)	$	4,492	$	4,062	$	430	$	—	$	—
Lease payments	$	43,935	$	10,313	$	19,919	$	8,968	$	4,735

We expect cash requirements totaling approximately $75.3 million for contributions to our pension plans in 2013, which includes approximately $57.1 million for our Power Generation segment and $18.2 million for Corporate. In addition, we anticipate cash requirements totaling approximately $13.3 million for contributions to our other postretirement benefit plans in 2013, which includes approximately $2.1 million to our funded postretirement benefit arrangements in our Nuclear Operations segment.

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(a) Interest payments on these borrowings as of December 31, 2012 are not significant.

Our contingent commitments under letters of credit, bank guarantees and surety bonds currently outstanding expire as follows:

Total		Less than 1 Year		1-3 Years		3-5 Years		Thereafter
(In thousands)
$	685,986	$	295,484	$	46,054	$	326,599	$	17,849

Item 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our exposure to market risk from changes in interest rates relates primarily to our cash equivalents and our investment portfolio, which primarily consists of investments in U.S. Government obligations and highly liquid money market instruments denominated in U.S. dollars. We are averse to principal loss and seek to ensure the safety and preservation of our invested funds by limiting default risk, market risk and reinvestment risk. All our investments in debt securities are classified as available-for-sale.

We have exposure to changes in interest rates on the Credit Agreement (see Item 7 – “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources”). At December 31, 2012, we had no outstanding borrowings under this facility. We have no material future earnings or cash flow exposures from changes in interest rates on our other long-term debt obligations.

We have operations in many foreign locations, and, as a result, our financial results could be significantly affected by factors such as changes in foreign currency exchange rates or weak economic conditions in those foreign markets. In order to manage the risks associated with foreign currency exchange rate fluctuations, we attempt to hedge those risks with foreign currency derivative instruments. Historically, we have hedged those risks with foreign currency forward contracts. We do not enter into speculative derivative positions.

Interest Rate Sensitivity

The following tables provide information about our financial instruments that are sensitive to changes in interest rates. The tables present principal cash flows and related weighted-average interest rates by expected maturity dates.

	Principal Amount by Expected Maturity
	(In thousands)
At December 31, 2012:																				Fair Value at
	Years Ending December 31,																			December 31,
	2013			2014			2015			2016			2017		Thereafter			Total		2012
Investments	$	88,750			—			—			—			—	$	3,511		$	92,261	$	92,859
Average Interest Rate		0.29	%		—			—			—			—		0.36	%
Long-term Debt	$	4,062		$	215		$	215			—			—		—		$	4,492	$	4,529
Average Interest Rate		6.28	%		0.46	%		0.46	%		—			—		—
At December 31, 2011:																				Fair Value at
	Years Ending December 31,																			December 31,
	2012			2013			2014			2015			2016		Thereafter			Total		2011
Investments	$	69,422			—			—			—			—	$	2,957		$	72,379	$	72,580
Average Interest Rate		0.24	%		—			—			—			—		0.37	%
Long-term Debt	$	4,653		$	205		$	210		$	218			—		—		$	5,286	$	5,350
Average Interest Rate		6.99	%		1.97	%		1.97	%		1.97	%		—		—

55

Exchange Rate Sensitivity

The following table provides information about our foreign currency exchange (“FX”) forward contracts outstanding at December 31, 2012 and presents such information in U.S. dollar equivalents. The table presents notional amounts and related weighted-average FX rates by expected (contractual) maturity dates and constitutes a forward-looking statement. These notional amounts generally are used to calculate the contractual payments to be exchanged under the contract. The average contractual FX rates are expressed using market convention, which is dependent on the currencies being bought and sold under the forward contract.

Forward Contracts to Purchase Foreign Currencies in U.S. Dollars (in thousands)

Foreign Currency	Year Ending December 31, 2013		Fair Value at December 31, 2012			Average Contractual Exchange Rate
British Pound Sterling	$	707	$	11			1.5832
British Pound Sterling (selling Euros)	$	855	$	(14	)		0.8094
Canadian Dollars	$	42,724	$	1,527			1.0383
Canadian Dollars (selling Japanese Yen)	$	6,542	$	580			78.7183
Danish Krone	$	13,771	$	28			5.6342
Danish Krone (selling Swedish Krona)	$	16,374	$	(1,479	)		1.2636
Euros	$	1,661	$	52			1.2852
Euros (selling Canadian Dollars)	$	195	$	4			1.2956
Euros (selling Swedish Krona)	$	284	$	(18	)		9.1843
Japanese Yen (selling Canadian Dollars)	$	14,636	$	(1,335	)		78.2112
Swedish Krona (selling Danish Krona)	$	2,368	$	34			1.1712
Swedish Krona (selling Euros)	$	213	$	14			9.2215
U.S. Dollars (selling Canadian Dollars)	$	447	$	(7	)		1.0113
Foreign Currency	Year Ending December 31, 2014		Fair Value at December 31, 2012			Average Contractual Exchange Rate
British Pound Sterling	$	6,230	$	191			1.5583
Canadian Dollars	$	62,777	$	3,759			1.0725
U.S. Dollars (selling Canadian Dollars)	$	467	$	(12	)		1.0337

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

56

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Stockholders of The Babcock & Wilcox Company:

We have audited the accompanying consolidated balance sheets of The Babcock & Wilcox Company and subsidiaries (the “Company”) as of December 31, 2012 and 2011, and the related consolidated and combined statements of income, comprehensive income, stockholders’ equity, and cash flows for each of the three years in the period ended December 31, 2012. These consolidated and combined financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated and combined financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such consolidated and combined financial statements present fairly, in all material respects, the financial position of The Babcock & Wilcox Company and subsidiaries as of December 31, 2012 and 2011, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2012, in conformity with accounting principles generally accepted in the United States of America.

As discussed in Note 1 to the consolidated and combined financial statements, on December 31, 2012, the Company has elected to change its method of recognizing actuarial gains and losses for pension and other postretirement benefit plans.

As discussed in Note 1 to the consolidated and combined financial statements, on and prior to July 30, 2010, the combined financial statements were prepared from the separate records maintained by the Company and may not necessarily be indicative of the conditions that would have existed or the results of operations of the Company had it been operated as an independent entity.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2012, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2013 expressed an unqualified opinion on the Company’s internal control over financial reporting.

/S/ DELOITTE & TOUCHE LLP

Charlotte, North Carolina

February 27, 2013

57

THE BABCOCK & WILCOX COMPANY

CONSOLIDATED BALANCE SHEETS

	December 31,
	2012		2011
	(In thousands)
ASSETS
Current Assets:
Cash and cash equivalents	$	383,547	$	415,209
Restricted cash and cash equivalents		60,961		61,190
Investments		88,769		68,805
Accounts receivable – trade, net		364,960		305,832
Accounts receivable – other		61,682		77,505
Contracts in progress		316,518		315,286
Inventories		124,218		107,298
Deferred income taxes		78,573		102,022
Other current assets		41,858		33,929
Total Current Assets		1,521,086		1,487,076
Property, Plant and Equipment		1,099,040		1,017,422
Less accumulated depreciation		652,019		595,131
Net Property, Plant and Equipment		447,021		422,291
Investments		4,090		3,775
Goodwill		280,780		276,180
Deferred Income Taxes		227,215		241,739
Investments in Unconsolidated Affiliates		186,354		163,568
Other Assets		173,809		194,482
TOTAL	$	2,840,355	$	2,789,111

See accompanying notes to consolidated and combined financial statements.

58

THE BABCOCK & WILCOX COMPANY

CONSOLIDATED BALANCE SHEETS

	December 31,
	2012			2011
	(In thousands)
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Notes payable and current maturities of long-term debt	$	4,062		$	4,653
Accounts payable		264,798			237,494
Accrued employee benefits		186,495			303,803
Accrued liabilities – other		57,991			71,079
Advance billings on contracts		472,287			438,753
Accrued warranty expense		83,682			97,209
Income taxes payable		9,973			1,816
Total Current Liabilities		1,079,288			1,154,807
Long-Term Debt		430			633
Accumulated Postretirement Benefit Obligation		71,208			80,663
Environmental Liabilities		46,497			44,069
Pension Liability		579,165			586,045
Other Liabilities		60,851			87,921
Commitments and Contingencies (Note 10)
Stockholders’ Equity:
Common stock, par value $0.01 per share, authorized 325,000,000 shares; issued 119,608,026 and 118,458,911 shares at December 31, 2012 and December 31, 2011, respectively		1,196			1,185
Preferred stock, par value $0.01 per share, authorized 75,000,000 shares; no shares issued		—			—
Capital in excess of par value		713,257			676,952
Retained earnings		349,063			130,890
Treasury stock at cost, 4,372,143 and 351,876 shares at December 31, 2012 and December 31, 2011, respectively		(109,809	)		(10,059	)
Accumulated other comprehensive income		32,728			26,826
Stockholders’ Equity – The Babcock & Wilcox Company		986,435			825,794
Noncontrolling interest		16,481			9,179
Total Stockholders’ Equity		1,002,916			834,973
TOTAL	$	2,840,355		$	2,789,111

See accompanying notes to consolidated and combined financial statements.

59

THE BABCOCK & WILCOX COMPANY

CONSOLIDATED AND COMBINED STATEMENTS OF INCOME

	Year Ended December 31,
	2012			2011			2010
	(In thousands, except per share amounts)
Revenues	$	3,291,359		$	2,952,040		$	2,688,811
Costs and Expenses:
Cost of operations		2,461,205			2,384,154			2,032,347
Research and development costs		120,562			106,396			69,167
Losses (gains) on asset disposals and impairments – net		1,419			(3,087	)		38
Selling, general and administrative expenses		428,293			447,561			412,486
Total Costs and Expenses		3,011,479			2,935,024			2,514,038
Equity in Income of Investees		66,709			78,655			74,082
Operating Income		346,589			95,671			248,855
Other Income (Expense):
Interest income		1,491			1,342			1,187
Interest expense		(3,735	)		(4,543	)		(12,938	)
Other income (expense) – net		(24,927	)		2,028			(16,896	)
Total Other Expense		(27,171	)		(1,173	)		(28,647	)
Income before Provision for Income Taxes		319,418			94,498			220,208
Provision for Income Taxes		101,861			23,880			80,005
Net Income	$	217,557		$	70,618		$	140,203
Net Loss (Income) Attributable to Noncontrolling Interest		10,138			7,701			(264	)
Net Income Attributable to The Babcock & Wilcox Company	$	227,695		$	78,319		$	139,939
Earnings per Common Share:
Basic:
Net Income Attributable to The Babcock & Wilcox Company	$	1.92		$	0.67		$	1.20
Diluted:
Net Income Attributable to The Babcock & Wilcox Company	$	1.91		$	0.66		$	1.19
Shares used in the computation of earnings per share (Note 19):
Basic		118,418,930			117,560,594			116,260,425
Diluted		119,021,324			118,404,597			117,626,065

See accompanying notes to consolidated and combined financial statements.

60

THE BABCOCK & WILCOX COMPANY

CONSOLIDATED AND COMBINED STATEMENTS OF

COMPREHENSIVE INCOME

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Net Income	$	217,557		$	70,618		$	140,203
Other Comprehensive Income (Loss):
Foreign currency translation adjustments:
Foreign currency translation adjustments		4,284			747			7,561
Unrealized gains (losses) on derivative financial instruments:
Unrealized gains (losses) on derivative financial instruments		1,409			(877	)		6,407
Reclassification adjustment for gains (losses) included in net income		(2,023	)		1,655			1,290
Unrecognized losses on benefit obligations:
Unrecognized losses arising during the period		(434	)		(1,205	)		(551	)
Amortization of losses included in net income		2,281			2,487			2,386
Unrealized gains (losses) on investments:
Unrealized gains (losses) arising during the period		431			(74	)		523
Reclassification adjustment for net (losses) gains included in net income		(35	)		5			122
Other Comprehensive Income		5,913			2,738			17,738
Total Comprehensive Income		223,470			73,356			157,941
Comprehensive Loss (Income) Attributable to Noncontrolling Interest		10,127			7,670			(243	)
Comprehensive Income Attributable to The Babcock & Wilcox Company	$	233,597		$	81,026		$	157,698

See accompanying notes to consolidated and combined financial statements.

61

THE BABCOCK & WILCOX COMPANY

CONSOLIDATED AND COMBINED STATEMENT OF STOCKHOLDERS’ EQUITY

	Common Stock				Capital In Excess of			Retained			Accumulated Other Comprehensive			Treasury			Parent			Non- Controlling			Total Stockholders’
	Shares		Par Value		Par Value			Earnings			Income (Loss)			Stock			Equity			Interest			Equity
	(In thousands, except share amounts)
Balance December 31, 2009		—	$	—	$	—		$	—		$	8,216		$	—		$	111,987		$	503		$	120,706
Net income		—		—		—			52,571			—			—			87,368			264			140,203
Amortization of benefit plan costs		—		—		—			—			2,386			—			—			—			2,386
Unrealized loss on benefit obligations		—		—		—			—			(551	)		—			—			—			(551	)
Unrealized gain on investments		—		—		—			—			645			—			—			—			645
Translation adjustments		—		—		—			—			7,582			—			—			(21	)		7,561
Unrealized gain on derivatives		—		—		—			—			7,697			—			—			—			7,697
Transfer of pension to Parent		—		—		—			—			1,544			—			—			—			1,544
Dividend paid		—		—		—			—			—			—			(100,000	)		—			(100,000	)
Net transactions with Parent		—		—		—			—			(3,400	)		—			523,566			—			520,166
Reclassification of Parent equity to capital in excess of par value		—		—		622,921			—			—			—			(622,921	)		—			—
Issuance of common stock at spin-off		116,225,732		1,162		(1,162	)		—			—			—			—			—			—
Exercise of stock options		86,004		1		3,427			—			—			—			—			—			3,428
Contributions to thrift plan		218,699		2		5,171			—			—			—			—			—			5,173
Shares placed in treasury		—		—		—			—			—			(2,397	)		—			—			(2,397	)
Stock-based compensation charges		433,229		5		7,039			—			—			—			—			—			7,044
Distributions to noncontrolling interests		—		—		—			—			—			—			—			(80	)		(80	)
Balance December 31, 2010		116,963,664	$	1,170	$	637,396		$	52,571		$	24,119		$	(2,397	)	$	—		$	666		$	713,525
Net income		—		—		—			78,319			—			—			—			(7,701	)		70,618
Amortization of benefit plan costs		—		—		—			—			2,487			—			—			—			2,487
Unrealized loss on benefit obligations		—		—		—			—			(1,205	)		—			—			—			(1,205	)
Unrealized loss on investments		—		—		—			—			(69	)		—			—			—			(69	)
Translation adjustments		—		—		—			—			716			—			—			31			747
Unrealized gain on derivatives		—		—		—			—			778			—			—			—			778
Exercise of stock options		379,706		4		8,542			—			—			—			—			—			8,546
Contributions to thrift plan		510,510		5		13,093			—			—			—			—			—			13,098
Shares placed in treasury		—		—		—			—			—			(7,662	)		—			—			(7,662	)
Stock-based compensation charges		605,031		6		17,921			—			—			—			—			—			17,927
Contribution of in-kind services		—		—		—			—			—			—			—			16,584			16,584
Distributions to noncontrolling interests		—		—		—			—			—			—			—			(401	)		(401	)
Balance December 31, 2011		118,458,911	$	1,185	$	676,952		$	130,890		$	26,826		$	(10,059	)	$	—		$	9,179		$	834,973
Net income		—		—		—			227,695			—			—			—			(10,138	)		217,557
Dividends declared ($.08 per share)		—		—		—			(9,522	)		—			—			—			—			(9,522	)
Amortization of benefit plan costs		—		—		—			—			2,281			—			—			—			2,281
Unrealized loss on benefit obligations		—		—		—			—			(434	)		—			—			—			(434	)
Unrealized gain on investments		—		—		—			—			396			—			—			—			396
Translation adjustments		—		—		—			—			4,273			—			—			11			4,284
Unrealized loss on derivatives		—		—		—			—			(614	)		—			—			—			(614	)
Exercise of stock options		261,784		3		4,511			—			—			—			—			—			4,514
Contributions to thrift plan		549,121		5		13,788			—			—			—			—			—			13,793
Shares placed in treasury		—		—		—			—			—			(99,750	)		—			—			(99,750	)
Stock-based compensation charges		338,210		3		18,006			—			—			—			—			—			18,009
Contribution of in-kind services		—		—		—			—			—			—			—			17,942			17,942
Distributions to noncontrolling interests		—		—		—			—			—			—			—			(513	)		(513	)
Balance December 31, 2012		119,608,026	$	1,196	$	713,257		$	349,063		$	32,728		$	(109,809	)	$	—		$	16,481		$	1,002,916

See accompanying notes to consolidated and combined financial statements.

62

THE BABCOCK & WILCOX COMPANY

CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net Income	$	217,557		$	70,618		$	140,203
Non-cash items included in net income:
Depreciation and amortization		69,697			73,003			71,633
Income of investees, net of dividends		(15,115	)		(20,854	)		(20,449	)
Losses (gains) on asset disposals and impairments – net		1,419			(3,087	)		38
Impairment of USEC investment		27,000			—			—
In-kind research and development costs		17,942			16,584			—
Provision for (benefit from) deferred taxes		43,038			(19,200	)		31,168
Recognition of losses and prior service cost for pension and postretirement plans		35,480			219,508			95,547
Stock-based compensation expense		18,009			17,927			16,308
Excess tax benefits from stock-based compensation		(1,571	)		(4,083	)		(5,276	)
Changes in assets and liabilities, net of effects from acquisitions:
Accounts receivable		(52,034	)		(26,887	)		101,260
Accounts payable		30,391			48,246			19,882
Net contracts in progress and advance billings		32,527			(28,746	)		(153,933	)
Income taxes		5,522			31,961			9,239
Accrued and other current liabilities		(30,553	)		(23,106	)		(9,761	)
Pension liability and accrued postretirement and employee benefits		(168,004	)		(144,802	)		(85,371	)
Other		(46,378	)		(33,491	)		(18,082	)
NET CASH PROVIDED BY OPERATING ACTIVITIES		184,927			173,591			192,406
CASH FLOWS FROM INVESTING ACTIVITIES:
Decrease (increase) in restricted cash and cash equivalents		229			(48,923	)		3,038
Purchases of property, plant and equipment		(86,635	)		(63,874	)		(63,649	)
Acquisition of businesses, net of cash acquired		(318	)		(11,907	)		(29,962	)
Purchases of available-for-sale securities		(268,929	)		(145,198	)		(135,135	)
Sales and maturities of available-for-sale securities		247,649			147,288			134,276
Proceeds from asset disposals		580			6,468			753
Proceeds from sale of an unconsolidated affiliate		2,091			—			—
Investments, net of return of capital, in equity and cost method investees		(6,064	)		(38,176	)		(42,912	)
Decrease in note receivable from affiliate		—			—			43,277
NET CASH USED IN INVESTING ACTIVITIES		(111,397	)		(154,322	)		(90,314	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payment of short-term borrowings and long-term debt		(4,643	)		(1,782	)		(29,914	)
Payment of debt issuance costs		(4,902	)		(82	)		(9,994	)
Increase in short-term borrowing		3,815			1,254			25,000
Repurchase of common shares		(96,774	)		—			—
Dividends paid to common shareholders		(9,485	)		—			—
Dividend paid to McDermott International, Inc.		—			—			(100,000	)
Capital contribution from McDermott International, Inc.		—			—			12,501
Distribution to McDermott International, Inc.		—			—			(43,334	)
(Decrease) Increase in notes payable to affiliates		—			—			(43,386	)
Exercise of stock options		2,926			4,463			211
Excess tax benefits from stock-based compensation		1,571			4,083			5,276
Other		(514	)		(401	)		(93	)
NET CASH (USED IN) PROVIDED BY FINANCING ACTIVITIES		(108,006	)		7,535			(183,733	)
EFFECTS OF EXCHANGE RATE CHANGES ON CASH		2,814			(2,737	)		3,315
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS		(31,662	)		24,067			(78,326	)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD		415,209			391,142			469,468
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	383,547		$	415,209		$	391,142
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest (net of amount capitalized)	$	3,842		$	4,525		$	3,746
Income taxes (net of refunds)	$	83,062		$	33,505		$	27,227

See accompanying notes to consolidated and combined financial statements.

63

THE BABCOCK & WILCOX COMPANY

NOTES TO CONSOLIDATED AND COMBINED FINANCIAL STATEMENTS

DECEMBER 31, 2012

NOTE 1 – BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

We have presented the consolidated and combined financial statements of The Babcock & Wilcox Company (“B&W”) in U.S. Dollars in accordance with accounting principles generally accepted in the United States (“GAAP”). On and prior to July 30, 2010, our financial position, operating results and cash flows consisted of The Babcock & Wilcox Operations of McDermott International, Inc., (“BWO”), which represented a combined reporting entity comprised of the assets and liabilities involved in managing and operating what was previously the Power Generation Systems and Government Operations segments of McDermott International, Inc., a Panamanian corporation (“MII”). In addition, two captive insurance companies were combined and contributed to B&W in conjunction with the spin-off of B&W by MII. On our consolidated and combined statements of income and cash flows, the twelve months ended December 31, 2010 include the combined results of operations for seven months of BWO and five months of the consolidated results of B&W.

B&W was a wholly owned subsidiary of MII until July 30, 2010 when MII distributed 100% of our outstanding common stock to the MII shareholders. On July 2, 2010, MII’s Board of Directors approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of MII common stock. The distribution of B&W common stock was made on July 30, 2010, and consisted of one share of B&W common stock for every two shares of MII common stock to holders of MII common stock as of 5:00 p.m. New York City time on the record date, July 9, 2010. Cash was paid in lieu of any fractional shares of B&W common stock. B&W became a separate publicly traded company, and MII did not retain any ownership interest in B&W. A registration statement on Form 10 describing the spin-off was filed by B&W with the Securities and Exchange Commission and was declared effective on July 8, 2010 (as amended through the time of such effectiveness).

We use the equity method to account for investments in entities that we do not control, but over which we have the ability to exercise significant influence. We generally refer to these entities as “joint ventures.” We have eliminated all intercompany transactions and accounts.

Certain corporate and general and administrative expenses incurred before the spin-off, including those related to executive management, investor relations, tax, accounting, legal and treasury services, and certain employee benefits, have been allocated based on a level of effort calculation. Our management believes such allocations are reasonable. However, the associated expenses reflected in the accompanying consolidated and combined statements of income may not be indicative of the actual expenses that would have been incurred had the combined businesses been operating as an independent public company for all periods presented. Since the spin-off from MII, B&W has been performing these functions using internal resources or services provided by third parties, certain of which were provided by MII during a transitional period pursuant to a transition services agreement. We have terminated most of the services under the transition services agreement.

Unless the context otherwise indicates, “we,” “us” and “our” mean B&W and its consolidated and combined subsidiaries.

Pension Accounting Change

In the fourth quarter of 2012, we elected to change our accounting method for recognizing actuarial gains and losses for our pension and other postretirement benefit plans. Historically, these gains and losses were recognized as a component of accumulated other comprehensive income on our consolidated balance sheets and we amortized these actuarial gains and losses into earnings over the average remaining service period for our Canadian plans to the extent such gains and losses exceeded a corridor and for our domestic plans we used an amortization method over the average remaining service period without the use of a corridor. Under our new accounting method, we will immediately recognize actuarial gains and losses into earnings in the fourth quarter each year as a component of net periodic benefit cost. This new accounting method results in actuarial gains and losses being recognized faster than our previous amortization method. We believe the new accounting method is preferable as this accelerated method recognizes the effects of plan investment performance, interest rate movements and changes in other actuarial assumptions as a component of earnings in the period they occur. This change has been reported through

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retrospective application of the new accounting method to all periods presented. See Note 6 for a further discussion of our pension and postretirement benefits and Note 20 for disclosures relating to the effect of this change in our accounting method.

Business Segments

We operate in four business segments: Power Generation, Nuclear Operations, Technical Services and Nuclear Energy. For financial information about our segments, see Note 17 to our consolidated and combined financial statements included in this report.

Our segments are further described as follows:

• Our Power Generation segment supplies boilers fired with fossil fuels, such as coal, oil and natural gas, or renewable fuels such as biomass and municipal solid waste. In addition, we supply environmental equipment and components and related services to customers in different regions around the world. This segment owns or leases manufacturing facilities in the U.S., Canada, Denmark, Germany, Mexico, China and Scotland. We design, engineer, manufacture, supply, construct and service large utility and industrial power generation systems, including boilers used to generate steam in electric power plants, pulp and paper making, chemical and process applications and other industrial uses. We also provide the same compliment of services for our renewable portfolio of boiler technology, which includes biomass fired, waste-to-energy and concentrated solar energy for steam generating solutions. In addition, this segment is a technological leader in providing cost-effective and efficient air pollution control solutions and material handling systems. We have successfully developed advanced technologies to control nitrogen oxides, sulfur dioxide, fine particulate, mercury, acid gases and other hazardous air emissions. In addition, our Power Generation segment offers a variety of construction services for the entire balance of plant, from large steam generation or environmental equipment projects, to cogeneration and combined cycle installations. This segment also offers a full suite of aftermarket services. Our Power Generation segment’s full-scope boiler, environmental and auxiliary equipment retrofits, upgrades and services improve plant performance and efficiency and extend the life of vital steam generating assets.

• Our Nuclear Operations segment manufactures naval nuclear reactors for the U.S. Department of Energy (“DOE”)/National Nuclear Security Administration’s (“NNSA”) Naval Nuclear Propulsion Program, which in turn supplies them to the U.S. Navy for use in submarines and aircraft carriers. Through this segment, we own and operate manufacturing facilities located in Lynchburg, Virginia; Mount Vernon, Indiana; Euclid, Ohio; Barberton, Ohio; and Erwin, Tennessee. The Barberton, Ohio and Mount Vernon, Indiana locations specialize in the design and manufacture of heavy components. These two locations are N-Stamp accredited by the American Society of Mechanical Engineers (“ASME”), making them two of only a few North American suppliers of large, heavy-walled nuclear components and vessels. The Euclid, Ohio facility, which is also ASME N-Stamp certified, fabricates electro-mechanical equipment for the U.S. Government, and performs design, manufacturing, inspection, assembly and testing activities. The Lynchburg, Virginia operations fabricate fuel-bearing precision components that range in weight from a few grams to hundreds of tons. In-house capabilities also include wet chemistry uranium processing, advanced heat treatment to optimize component material properties and a controlled, clean-room environment with the capacity to assemble railcar-size components. Fuel for the naval nuclear reactors is provided by Nuclear Fuel Services, Inc. (“NFS”), one of our wholly owned subsidiaries. Located in Erwin, Tennessee, NFS also converts cold war-era government stockpiles of highly enriched uranium into material suitable for further processing into commercial nuclear reactor fuel.

• Our Technical Services segment provides various services to the U.S. Government, including uranium processing, environmental site restoration services and management and operating services for various U.S. Government-owned facilities. These services are provided to the DOE, including the NNSA, the Office of Nuclear Energy, the Office of Science, the Department of Defense and the Office of Environmental Management, and through this segment we deliver products and management solutions to nuclear operations and high-consequence manufacturing facilities. A significant portion of this segment’s operations are conducted through joint ventures.

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• Our Nuclear Energy segment supplies commercial nuclear steam generators and components to nuclear utility customers. In addition, this segment is actively designing the modular and scalable B&W mPower^TM reactor. B&W has supplied the nuclear industry with more than 1,300 large, heavy components worldwide. With manufacturing operations in the U.S. and Canada, this segment is the only heavy nuclear component, N-Stamp certified manufacturer in North America. Our Nuclear Energy segment fabricates pressure vessels, reactors, steam generators, heat exchangers and other auxiliary equipment. This segment also provides specialized engineering services that include structural component design, 3-D thermal-hydraulic engineering analysis, weld and robotic process development and metallurgy and materials engineering. Our Nuclear Energy segment also provides power plant construction and management and maintenance services. In addition, this segment offers services for nuclear steam generators and balance of plant equipment, as well as nondestructive examination and tooling/repair solutions for other plant systems and components.

The consolidated results of operations, financial position and cash flows for the year ended December 31, 2012 are not necessarily indicative of the results that may be expected for the year ending December 31, 2013.

Use of Estimates

We use estimates and assumptions to prepare our financial statements in conformity with GAAP. Some of our more significant estimates include our estimate of costs to complete long-term construction contracts and estimates we make in selecting assumptions related to the valuations of our pension and postretirement plans, including the selection of our discount rates and expected rates of return on our pension plan assets. These estimates and assumptions affect the amounts we report in our financial statements and accompanying notes. Our actual results could differ from these estimates. Variances could result in a material effect on our financial condition and results of operations in future periods.

Earnings Per Share

We have computed earnings per common share on the basis of the weighted average number of common shares, and, where dilutive, common share equivalents, outstanding during the indicated periods. On July 30, 2010, 116,225,732 shares of our common stock were distributed to MII shareholders to complete our spin-off from MII. For comparative purposes, and to provide a more meaningful calculation of weighted average shares, we have assumed this amount to be outstanding as of the beginning of each period presented prior to our spin-off in our calculation of basic weighted average shares. In addition, for our dilutive weighted average share calculations, we have assumed the dilutive securities outstanding at July 30, 2010 were also outstanding at each of the periods presented prior to our spin-off.

Investments

Our investments, primarily U.S. Government obligations and other highly liquid money market instruments, are classified as available-for-sale and are carried at fair value, with the unrealized gains and losses, net of tax, reported as a component of accumulated other comprehensive income. We classify investments available for current operations in the consolidated balance sheets as current assets, while we classify investments held for long-term purposes as noncurrent assets. We adjust the amortized cost of debt securities for amortization of premiums and accretion of discounts to maturity. That amortization is included in interest income. We include realized gains and losses on our investments in other income (expense) – net. The cost of securities sold is based on the specific identification method. We include interest on securities in interest income.

Foreign Currency Translation

We translate assets and liabilities of our foreign operations into U.S. dollars at current exchange rates, and we translate income statement items at average exchange rates for the periods presented. We record adjustments resulting from the translation of foreign currency financial statements as a component of accumulated other comprehensive income. We report foreign currency transaction gains and losses in income. We have included in other income (expense)—net transaction losses of $0.6 million, $1.9 million and $6.5 million for the years ended December 31, 2012, 2011 and 2010, respectively.

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Contracts and Revenue Recognition

We generally recognize contract revenues and related costs on a percentage-of-completion method for individual contracts or combinations of contracts based on work performed, man hours, or a cost-to-cost method, as applicable to the product or activity involved. We recognize estimated contract revenue and resulting income based on the measurement of the extent of progress completion as a percentage of the total project. Certain costs may be excluded from the cost-to-cost method of measuring progress, such as significant costs for materials and major third party subcontractors, if it appears that such exclusion would result in a more meaningful measurement of actual contract progress and resulting periodic allocation of income. We include revenues and related costs so recorded, plus accumulated contract costs that exceed amounts invoiced to customers under the terms of the contracts, in contracts in progress. We include in advance billings on contracts billings that exceed accumulated contract costs and revenues and costs recognized under the percentage-of-completion method. Most long-term contracts contain provisions for progress payments. Our unbilled receivables do not contain an allowance for credit losses as we expect to invoice customers and collect all amounts for unbilled revenues. We review contract price and cost estimates periodically as the work progresses and reflect adjustments proportionate to the percentage-of-completion in income in the period when those estimates are revised. For all contracts, if a current estimate of total contract cost indicates a loss on a contract, the projected loss is recognized in full when determined.

For contracts as to which we are unable to estimate the final profitability except to assure that no loss will ultimately be incurred, we recognize equal amounts of revenue and cost until the final results can be estimated more precisely. For these deferred profit recognition contracts, we recognize revenue and cost equally and only recognize gross margin when probable and reasonably estimable, which we generally determine to be when the contract is approximately 70% complete. We treat long-term construction contracts that contain such a level of risk and uncertainty that estimation of the final outcome is impractical, except to assure that no loss will be incurred, as deferred profit recognition contracts.

Our policy is to account for fixed-price contracts under the completed-contract method if we believe that we are unable to reasonably forecast cost to complete at start-up. Under the completed-contract method, income is recognized only when a contract is completed or substantially complete.

For the majority of parts orders and certain aftermarket services activities, we recognize revenues as goods are delivered and work is performed.

Variations from estimated contract performance could result in material adjustments to operating results for any fiscal quarter or year. We include claims for extra work or changes in scope of work to the extent of costs incurred in contract revenues when we believe collection is probable.

In the year ended December 31, 2012, we recorded a contract loss totaling approximately $16.9 million, net of claims, based on our estimate of costs to complete a project in our Power Generation segment. In the year ended December 31, 2011, we recorded additional costs totaling approximately $61.8 million ($50.7 million in our Nuclear Energy segment and $11.1 in our Nuclear Operations segment) to complete certain projects attributable to changes in estimate due to productivity and scheduling issues. In May 2012, we entered into an agreement with the customer of the Nuclear Energy project to settle contract claims resulting in recognition of revenues totaling approximately $18.4 million in 2012. These projects are now complete.

Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and the applicable customer asserts a claim under these provisions. These contracts define the conditions and timing under which our customers may make claims against us for liquidated damages. In the majority of cases in which we have had potential exposure for liquidated damages, such damages ultimately were determined not to be caused by our actions or were not otherwise asserted by our customers. Accordingly, we do not accrue liabilities for liquidated damages unless probable and estimable. As of December 31, 2012, we had not accrued for approximately $6.0 million of potential liquidated damages that are not currently due under the particular contract but which we believe could be asserted based upon our current expectations of the time to complete a certain project in our Power Generation segment. We do not believe any of these potential liquidated damages are probable of being assessed due primarily to their relationship to unforeseen worksite conditions that we believe are the responsibility of our customer. We are in active discussions with our customer on the issues giving rise to delays in this project, and we believe we will be successful in obtaining schedule extensions that should resolve the potential for liquidated damages liability. However, we may not achieve relief on some or all of the issues.

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The following represent the components of our contracts in progress and advance billings on contracts included in our consolidated balance sheets:

	December 31,
	2012			2011
	(In thousands)
Included in Contracts in Progress:
Costs incurred less costs of revenue recognized	$	135,972		$	135,513
Revenues recognized less billings to customers		180,546			179,773
Contracts In Progress	$	316,518		$	315,286
Included In Advance Billings on Contracts:
Billings to customers less revenues recognized	$	541,983		$	492,106
Costs incurred less costs of revenue recognized		(69,696	)		(53,353	)
Advance Billings on Contracts	$	472,287		$	438,753

The following amounts represent retainages on contracts:

	December 31,
	2012		2011
	(In thousands)
Retainages expected to be collected within one year	$	85,776	$	60,158
Retainages expected to be collected after one year		28,661		14,526
Total retainages	$	114,437	$	74,684

We have included in accounts receivable – trade retainages expected to be collected in 2013. Retainages expected to be collected after one year are included in other assets. Of the long-term retainages at December 31, 2012, we anticipate collecting $23.1 million in 2014, $2.9 million in 2015 and $2.7 million in 2016.

Comprehensive Income

The components of accumulated other comprehensive income included in stockholders’ equity are as follows:

	December 31,
	2012			2011
	(In thousands)
Currency translation adjustments	$	40,899		$	36,626
Net unrealized gain on investments		597			201
Net unrealized gain on derivative financial instruments		2,103			2,717
Unrecognized prior service cost on benefit obligations		(10,871	)		(12,718	)
Accumulated other comprehensive income	$	32,728		$	26,826

Warranty Expense

We accrue estimated expense, included in cost of operations on our consolidated and combined statements of income, to satisfy contractual warranty requirements when we recognize the associated revenue on the related contracts. In addition, we make specific provisions or reductions where we expect the actual warranty costs to significantly differ from the accrued estimates. Such changes could have a material effect on our consolidated financial condition, results of operations and cash flows.

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The following summarizes the changes in the carrying amount of accrued warranty expense:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	97,209		$	109,588		$	115,055
Additions		20,972			21,267			31,660
Expirations and other changes		(24,766	)		(14,288	)		(28,032	)
Charges		(10,217	)		(19,035	)		(10,532	)
Translation and other		484			(323	)		1,437
Balance at end of period	$	83,682		$	97,209		$	109,588

Asset Retirement Obligations and Environmental Clean-up Costs

We accrue for future decommissioning of our nuclear facilities that will permit the release of these facilities to unrestricted use at the end of each facility’s life, which is a requirement of our licenses from the U.S. Nuclear Regulatory Commission (the “NRC”). In accordance with the FASB Topic Asset Retirement and Environmental Obligations, we record the fair value of a liability for an asset retirement obligation in the period in which it is incurred. When we initially record such a liability, we capitalize a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of a liability, we will settle the obligation for its recorded amount or incur a gain or loss. This topic applies to environmental liabilities associated with assets that we currently operate and are obligated to remove from service. For environmental liabilities associated with assets that we no longer operate, we have accrued amounts based on the estimated costs of clean-up activities for which we are responsible, net of any cost-sharing arrangements. We adjust the estimated costs as further information develops or circumstances change. An exception to this accounting treatment relates to the work we perform for two facilities for which the U.S. Government is obligated to pay substantially all of the decommissioning costs.

Substantially all of our asset retirement obligations relate to the remediation of our nuclear analytical laboratory and the NFS facility in our Nuclear Operations segment. The following table reflects our asset retirement obligations:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Balance at beginning of period	$	35,885	$	32,657		$	29,491
Costs incurred		—		(2,265	)		—
Additions/Adjustments		3,422		2,935			—
Accretion		3,059		2,558			3,166
Balance at end of period	$	42,366	$	35,885		$	32,657

Research and Development

Our research and development activities are related to the development and improvement of new and existing products and equipment, as well as conceptual and engineering evaluation for translation into practical applications. We charge to research and development cost the costs of research and development unrelated to specific contracts as incurred. Substantially all of these costs are in our Power Generation and Nuclear Energy segments and include costs related to the development of our modular nuclear reactor business, B&W mPower^TM. Contractual arrangements for customer-sponsored research and development can vary on a case-by-case basis and include contracts, cooperative agreements and grants. Research and development activities (including in-kind research and development services described below) totaled $173.9 million, $163.0 million and $102.1 million in the years ended December 31, 2012, 2011 and 2010, respectively, which include amounts paid for by our customers of $53.4 million, $56.6 million and $32.9 million, respectively.

During the years ended December 31, 2012 and 2011, we recognized $17.9 million and $16.6 million, respectively, of non-cash in-kind research and development costs (included above) related to services contributed by our minority partner to Generation mPower LLC (“GmP”), our majority-owned subsidiary formed in 2011 to oversee the program to develop the small modular nuclear power plant based on B&W mPower^TM technology.

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In November 2012, our Nuclear Energy segment was selected as the winner of the DOE’s competitively bid Small Modular Reactor (“SMR”) Licensing Technical Support Program, and will receive funding that will support accelerated development of its B&W mPower™ SMR technology.

Income Taxes

Income tax expense for federal, foreign, state and local income taxes are calculated on pre-tax income based on current tax law and include the cumulative effect of any changes in tax rates from those used previously in determining deferred tax assets and liabilities. We record a valuation allowance to reduce our deferred tax assets to the amount that is more likely than not to be realized. We assess deferred taxes and the adequacy of the valuation allowance on a quarterly basis. In the ordinary course of business there is inherent uncertainty in quantifying our income tax positions. We assess our income tax positions and record tax benefits for all years subject to examination based upon management’s evaluation of the facts, circumstances, and information available at the reporting date. For those tax positions where it is more-likely-than-not that a tax benefit will be sustained, we have recorded the largest amount of tax benefit with a greater than 50% likelihood of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. For those income tax positions where it is not more-likely-than-not that a tax benefit will be sustained, no tax benefit has been recognized in the financial statements. We record interest and penalties (net of any applicable tax benefit) related to income taxes as a component of provision for income taxes on our consolidated and combined statements of income.

Inventories

We carry our inventories at the lower of cost or market. We determine cost principally on the first-in, first-out basis, except for certain materials inventories of our Power Generation segment, for which we use the last-in, first-out (“LIFO”) method. We determined the cost of approximately 17% and 19% of our total inventories using the LIFO method at December 31, 2012 and 2011, respectively, and our total LIFO reserve at December 31, 2012 and 2011 was approximately $7.5 million and $7.1 million, respectively. Inventories are summarized below:

	December 31,
	2012		2011
	(In thousands)
Raw Materials and Supplies	$	98,428	$	77,932
Work in Progress		7,956		6,889
Finished Goods		17,834		22,477
Total Inventories	$	124,218	$	107,298

Property, Plant and Equipment

We carry our property, plant and equipment at depreciated cost, less any impairment provisions.

We depreciate our property, plant and equipment using the straight-line method over estimated economic useful lives of eight to 40 years for buildings and two to 28 years for machinery and equipment. Our depreciation expense was $59.4 million, $61.8 million and $61.1 million for the years ended December 31, 2012, 2011 and 2010, respectively.

We expense the costs of maintenance, repairs and renewals that do not materially prolong the useful life of an asset as we incur them.

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Property, plant and equipment is stated at cost and is set forth below:

	December 31,
	2012		2011
	(In thousands)
Land	$	11,875	$	11,656
Buildings		241,281		224,661
Machinery and equipment		776,678		710,666
Property under construction		69,206		70,439
		1,099,040		1,017,422
Less accumulated depreciation		652,019		595,131
Net Property, Plant and Equipment	$	447,021	$	422,291

Investments in Unconsolidated Affiliates

We use the equity method of accounting for affiliates in which we are able to exert significant influence. Currently, substantially all of our material investments in affiliates that are not consolidated are recorded using the equity method. Affiliates in which our investment ownership is less than 20% and where we are unable to exert significant influence are carried at cost.

Goodwill

The following summarizes the changes in the carrying amount of goodwill:

	Power Generation		Nuclear Operations			Technical Services		Nuclear Energy		Total
	(In thousands)
Balance at December 31, 2010	$	88,042	$	122,407		$	45,000	$	13,975	$	269,424
Acquisition of Loibl (Note 2)		11,015		—			—		—		11,015
Foreign currency translation adjustments and other		45		(4,304	)		—		—		(4,259	)
Balance at December 31, 2011	$	99,102	$	118,103		$	45,000	$	13,975	$	276,180
Purchase price adjustment for acquisition of Loibl (Note 2)		3,727		—			—		—		3,727
Foreign currency translation adjustments and other		873		—			—		—		873
Balance at December 31, 2012	$	103,702	$	118,103		$	45,000	$	13,975	$	280,780

Intangible Assets

We report our intangible assets in other assets. We amortize those intangible assets with definite lives to operating expense using the straight-line method.

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Other assets include the following intangible assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Amortized intangible assets:
Gross cost:
Customer relationships	$	36,644		$	40,051		$	37,167
Acquired backlog		2,979			22,435			19,335
Tradename		11,945			15,169			12,291
Unpatented technology		6,422			6,402			5,902
Patented technology		6,961			6,961			6,625
All other		7,912			7,901			11,935
Total	$	72,863		$	98,919		$	93,255
Accumulated amortization:
Customer relationships	$	(11,173	)	$	(8,618	)	$	(6,026	)
Acquired backlog		(1,457	)		(17,040	)		(12,701	)
Tradename		(6,422	)		(6,509	)		(4,260	)
Unpatented technology		(2,682	)		(2,033	)		(1,407	)
Patented technology		(4,235	)		(3,219	)		(2,096	)
All other		(4,343	)		(3,594	)		(6,296	)
Total	$	(30,312	)	$	(41,013	)	$	(32,786	)
Net amortized intangible assets	$	42,551		$	57,906		$	60,469
Unamortized intangible assets:
NRC category 1 license	$	43,830		$	43,830		$	43,830
Trademarks and trade names		1,305			1,305			1,305
Total unamortized intangible assets	$	45,135		$	45,135		$	45,135

The following summarizes the changes in the carrying amount of intangible assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	103,041		$	105,604		$	103,379
Business acquisitions & adjustments		(1,746	)		9,100			14,280
Amortization expense		(11,010	)		(11,545	)		(11,679	)
Impairment charge		(3,216	)		—			—
Foreign currency translation adjustments and other		617			(118	)		(376	)
Balance at end of period	$	87,686		$	103,041		$	105,604

We recognized an impairment charge totaling $3.2 million in the year ended December 31, 2012 related to the cancellation of an operations and maintenance services contract in our Power Generation segment.

The estimated amortization expense for the next five fiscal years is as follows (in thousands):

Year Ending December 31,	Amount
2013	$	8,023
2014	$	5,494
2015	$	4,292
2016	$	4,215
2017	$	3,944

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Other Non-Current Assets

We have included deferred debt issuance costs in other assets. We amortize deferred debt issuance costs as interest expense over the life of the related debt. The following summarizes the changes in the carrying amount of these assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	5,723		$	8,102		$	1,898
Additions		4,902			82			9,994
Interest expense – debt issuance costs		(2,157	)		(2,461	)		(3,790	)
Balance at end of period	$	8,468		$	5,723		$	8,102

Capitalization of Interest Cost

We capitalize interest in accordance with FASB Topic Interest. We incurred total interest of $4.9 million, $6.1 million and $14.8 million in the years ended December 31, 2012, 2011 and 2010, respectively, of which we capitalized $1.2 million, $1.6 million and $1.9 million in the years ended December 31, 2012, 2011 and 2010, respectively.

Cash and Cash Equivalents and Restricted Cash

Our cash equivalents are highly liquid investments, with maturities of three months or less when we purchase them.

We record cash and cash equivalents as restricted when we are unable to freely use such cash and cash equivalents for our general operating purposes. At December 31, 2012, we had restricted cash and cash equivalents totaling $63.9 million, $8.0 million of which was held in restricted foreign cash accounts, $2.9 million of which was held for future decommissioning of facilities (which is included in other assets on our consolidated balance sheets), $51.9 million of which was held to meet reinsurance reserve requirements of our captive insurer (in lieu of long-term investments), and $1.1 million of which was held in money market funds maintained by our captive insurer.

Derivative Financial Instruments

Our global operations give rise to exposure to market risks from changes in foreign exchange rates. We use derivative financial instruments to reduce the impact of changes in foreign exchange rates on our operating results. We use these instruments primarily to hedge our exposure associated with revenues or costs on our long-term contracts that are denominated in currencies other than our operating entities’ functional currencies. We do not hold or issue financial instruments for trading or other speculative purposes.

We enter into derivative financial instruments primarily as hedges of certain firm purchase and sale commitments denominated in foreign currencies. We record these contracts at fair value on our consolidated balance sheets. Depending on the hedge designation at the inception of the contract, the related gains and losses on these contracts are either deferred in stockholders’ equity (as a component of accumulated other comprehensive income) until the hedged item is recognized in earnings or offset against the change in fair value of the hedged firm commitment through earnings. Any ineffective portion of a derivative’s change in fair value is immediately recognized in earnings. The gain or loss on a derivative financial instrument not designated as a hedging instrument is also immediately recognized in earnings. Gains and losses on derivative financial instruments that require immediate recognition are included as a component of other income (expense) – net in our consolidated and combined statements of income.

Self-Insurance

We have a wholly owned insurance subsidiary that provides employer’s liability, general and automotive liability and workers’ compensation insurance and, from time to time, builder’s risk insurance (within certain limits) to our companies. We may also, in the future, have this insurance subsidiary accept other risks that we cannot or do not wish to transfer to outside insurance companies. Included in other liabilities on our consolidated balance sheets are reserves for self-insurance totaling $42.8 million and $43.6 million at December 31, 2012 and 2011, respectively. The reduction in 2012 was primarily attributable to a change in estimate recognized in cost of operations in our consolidated and combined statements of income.

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Loss Contingencies

We estimate liabilities for loss contingencies when it is probable that a liability has been incurred and the amount of loss is reasonably estimable. We provide disclosure when there is a reasonable possibility that the ultimate loss will exceed the recorded provision or if such probable loss is not reasonably estimable. We are currently involved in some significant litigation, as discussed in Note 10. Our losses are typically resolved over long periods of time and are often difficult to assess and estimate due to, among other reasons, the possibility of multiple actions by third parties; the attribution of damages, if any, among multiple defendants; plaintiffs, in most cases involving personal injury claims, do not specify the amount of damages claimed; the discovery process may take multiple years to complete; during the litigation process, it is common to have multiple complex unresolved procedural and substantive issues; the potential availability of insurance and indemnity coverages; the wide-ranging outcomes reached in similar cases, including the variety of damages awarded; the likelihood of settlements for de minimus amounts prior to trial; the likelihood of success at trial; and the likelihood of success on appeal. Consequently, it is possible future earnings could be affected by changes in our assessments of the probability that a loss has been incurred in a material pending litigation against us and/or changes in our estimates related to such matters.

Stock-Based Compensation

We expense stock-based compensation in accordance with FASB Topic Compensation – Stock Compensation. Under this topic, the fair value of equity-classified awards, such as restricted stock, performance shares and stock options, is determined on the date of grant and is not remeasured. The fair value of liability-classified awards, such as cash-settled stock appreciation rights, restricted stock units and performance units, is determined on the date of grant and is remeasured at the end of each reporting period through the date of settlement. Grant date fair values for restricted stock, restricted stock units, performance shares and performance units are determined using the closing price of our common stock on the date of grant. Grant date fair values for stock options and stock appreciation rights are determined using a Black-Scholes option-pricing model (“Black-Scholes”). The determination of the fair value of a share-based payment award using an option-pricing model requires the input of highly subjective assumptions, such as the expected life of the award and stock price volatility. Prior to August 1, 2010, all of our stock-based compensation expense was attributable to our participation in MII legacy stock-based compensation plans. Expense recognized prior to August 1, 2010 was based on the fair value of MII’s stock-based compensation awards.

Under the provisions of this FASB topic, we recognize expense, net of an estimated forfeiture rate, for all share-based awards granted on a straight-line basis over the requisite service periods of the awards, which is generally equivalent to the vesting term. This topic requires compensation expense to be recognized, net of an estimate for forfeitures, such that compensation expense is recorded only for those awards expected to vest. We review the estimate for forfeitures periodically and record any adjustments deemed necessary for each reporting period. If our actual forfeiture rate is materially different from our estimate, the stock-based compensation expense could be significantly different from what we have recorded in the current period.

Additionally, this FASB topic amended FASB Topic Statement of Cash Flows, to require excess tax benefits to be reported as a financing cash flow, rather than as a reduction of taxes paid. These excess tax benefits result from tax deductions in excess of the cumulative compensation expense recognized for options exercised and other equity-classified awards.

See Note 9 for a further discussion of stock-based compensation.

Recently Adopted Accounting Standards

In September 2011, the Financial Accounting Standards Board (“FASB”) issued an update to Topic Intangibles—Goodwill and Other. This update permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test currently required under this topic. On January 1, 2012, we adopted this update. The adoption of these provisions did not have an impact on our financial statements.

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In June 2011, the FASB issued an update to Topic Comprehensive Income. This update requires that comprehensive income be presented either in a single continuous statement or in two separate but consecutive statements. In the two-statement approach, the first statement would present the components of net income consistent with the statement of income format currently utilized and the second statement would present total other comprehensive income, the components of other comprehensive income, and the total of comprehensive income. There are no changes to the components that must be reported in other comprehensive income or when a component of other comprehensive income must be reclassified to net income. On January 1, 2012, we adopted this update. The adoption of these provisions did not have an impact on our financial statements.

In May 2011, the FASB issued an update to Topic Fair Value Measurement. This update reflects joint efforts by the FASB and International Accounting Standards Board to develop a converged fair value framework on how to measure fair value and what fair value measurement disclosures to provide. On January 1, 2012, we adopted this update. The adoption of these provisions did not have an impact on our financial statements.

New Accounting Standards

In July 2012, the FASB issued an update to Topic Intangibles—Goodwill and Other. This update permits an entity to first assess qualitative factors to determine whether it is more likely than not that an indefinite-lived intangible asset is impaired as a basis for determining whether it is necessary to perform the quantitative impairment test currently required under this topic. This update will be effective for us in 2013. We do not expect the adoption of this update to impact our financial statements.

In February 2013, the FASB issued an update to Topic Comprehensive Income. This update requires an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to present, either on the face of the statement of income or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. This update will be effective for us in 2013. We do not expect the adoption of this update to have a material impact on our financial statements.

NOTE 2 – BUSINESS ACQUISITIONS AND INVESTMENTS

Anlagenbau und Fördertechnik Arthur Loibl GmbH

In November 2011, our Power Generation segment, acquired Anlagenbau und Fördertechnik Arthur Loibl GmbH (“Loibl”) for approximately $24.2 million. The acquisition of Loibl, a German-based manufacturer of material handling equipment, will expand the products, services and global reach of our Power Generation segment’s ash handling business, which is one of the world’s leading suppliers of ash handling solutions for the power generation and other industries.

In connection with the Loibl acquisition, we recorded goodwill of approximately $14.7 million, intangible assets of $7.6 million, property, plant and equipment of $2.5 million and other net liabilities totaling $0.9 million. During 2012, we finalized our purchase price allocation for the Loibl acquisition, resulting in an increase to goodwill of approximately $3.7 million. The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Customer relationships	$	3,200	8 years
Backlog	$	3,100	2 years
Tradename	$	800	5 years
Unpatented technology	$	500	12 years

GE Energy Businesses

On April 2, 2010, we acquired the assets of the electrostatic precipitator aftermarket and emissions monitoring

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business units of GE Energy, a division of General Electric Company, for approximately $21.4 million. This acquisition includes GE Energy’s electrostatic precipitator replacement parts and mechanical components product lines, performance-enhancing hardware, controls and software, remote diagnostics equipment and emissions monitoring products and services. These products and services are used by a wide variety of power generation and industrial customers to monitor and control particulates and other emissions from power plants, factories and other facilities. These business units maintain offices in the United States in Kansas City, Missouri; Folkston, Georgia; Newport News, Virginia and Hatfield, Pennsylvania, as well as locations in Germany and China.

In connection with the GE acquisition, we recorded goodwill of $4.8 million, property, plant and equipment of $4.0 million, intangible assets of $5.5 million, and other net assets totaling $7.1 million. The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Customer relationships	$	3,700	10 years
Patented technology	$	1,000	10 years
Backlog	$	400	1.5 years
Tradename	$	400	10 years

Götaverken Miljö AB

In January 2010, we acquired the net assets of Gőtaverken Miljő AB, a flue gas cleaning and energy recovery company based in Gothenburg, Sweden for approximately $8.6 million. In connection with this acquisition, we recorded goodwill of $3.2 million, intangible assets of $6.4 million, and other net liabilities totaling $1.0 million The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Patented technology	$	2,460	15 years
Customer relationships	$	2,120	12 years
Tradenames and trademarks	$	1,160	20 years
Backlog	$	610	0.5 years

None of these acquisitions, either individually or in the aggregate, were considered significant. The proforma effect of these acquisitions are not material to our results of operations.

USEC, Inc. Investment

In May 2010, our subsidiary Babcock & Wilcox Investment Company (“BWICO”) entered into an agreement with Toshiba Corporation (“Toshiba”), which was subsequently assigned to one of its subsidiaries, and USEC Inc. (“USEC”) to make a strategic investment in USEC totaling $200 million payable over three phases. In September 2010, following the satisfaction of certain conditions, including the availability to USEC’s American Centrifuge program of at least $2 billion in uncommitted funds under the DOE’s loan guarantee program for front-end nuclear fuel facilities and the establishment of a joint venture between us and USEC for supply by the joint venture of centrifuges and related equipment for the American Centrifuge program, we made a $37.5 million investment in USEC as part of a definitive agreement for us to make a total $100 million strategic investment in USEC.

In connection with our investment, we received 37,500 shares of USEC Series B-1 12.75% Convertible Preferred Stock and Warrants to purchase 3,125,000 shares of USEC Class B Common Stock at an exercise price of $7.50 per share, which are exercisable between January 1, 2015 and December 31, 2016, and a seat on USEC’s board of directors.

In 2011, we entered into a standstill agreement with USEC and Toshiba when it became apparent that USEC would not be able to satisfy the closing conditions applicable to the second phase of the strategic investment. Pursuant to the standstill agreement, each party agreed not to exercise its right to terminate the strategic investment agreement for a limited standstill period, as subsequently extended. USEC has been unable to satisfy the closing conditions to the second and third phases of the strategic investment and the limited standstill period, as extended, has expired. Currently, BWICO, Toshiba and USEC each have the right to terminate their obligations under the original strategic investment agreement.

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On June 12, 2012, USEC entered into a Cooperative Agreement with the DOE to provide funding for a cost-share research, development and demonstration (“RD&D”) program to enhance the technical and financial readiness of centrifuge technology for commercialization. The Cooperative Agreement provides for 80% DOE and 20% USEC cost sharing for work performed during the period from June 1, 2012 through December 31, 2013, with a total estimated cost of $350 million. The Cooperative Agreement will be incrementally funded and DOE funding was initially limited to $87.7 million until the DOE provides authorization for additional funding. Execution of the Cooperative Agreement satisfies the requirement of USEC’s credit facility that USEC shall have entered into a definitive agreement with the DOE for the RD&D program in order to continue spending on the American Centrifuge program. Under the credit facility, USEC can invest its 20% share of the costs under the RD&D program as long as the amount of the expenditures reimbursable to USEC under the RD&D program that have not yet been reimbursed does not exceed $50 million.

On August 1, 2012 USEC filed its quarterly report for the period ended June 30, 2012 on Form 10-Q with the Securities and Exchange Commission. This report contained several updated risk factors (along with other disclosures) concerning operational and structural issues facing USEC including, but not limited to, the future operations of USEC’s Paducah Gaseous Diffusion Plant, achievement of milestones under the RD&D program discussed above, approved funding for the RD&D program, achievement of milestones under a 2002 DOE-USEC Agreement to develop, demonstrate and deploy the American Centrifuge technology and possible failure to maintain compliance with listing requirements of the New York Stock Exchange which could result in a delisting of USEC’s common stock (which could require USEC to repurchase its convertible notes for cash and trigger a default under its credit facility). In addition, on August 15, 2012 Standard and Poor’s lowered its ratings on USEC, including the corporate credit rating to CCC from CCC+ along with a negative outlook. Standard and Poor’s also lowered its issue-level rating on USEC’s senior convertible notes due October 2014 to CC from CCC-. We determined, based on the facts and circumstances disclosed above, that a fair value determination of our cost-method investment in USEC Preferred Stock was warranted. We have established, with the assistance of a third party valuation firm, that the fair value of our investment in USEC Preferred Stock totals $19.1 million. Fair value was determined using a combination of an option pricing model and a probability of default methodology. We believe the gross unrealized loss on our USEC Preferred Stock investment is other than temporarily impaired, and as a result we have included in other income (expense)—net on our consolidated and combined statements of income an impairment charge totaling $27.0 million related to our investment in USEC Preferred Stock to write our investment down to its estimated fair value. We continue to support the American Centrifuge program through the ongoing manufacturing of components and technical support of the development program, and are presently exploring various restructuring alternatives with USEC and will continue to monitor these developments and evaluate our remaining investment in USEC Preferred Stock as new facts become available.

NOTE 3 – EQUITY METHOD INVESTMENTS

We have investments in entities that we account for using the equity method. The undistributed earnings of our equity method investees were $115.6 million and $98.4 million at December 31, 2012 and 2011, respectively.

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Summarized below is combined balance sheet and income statement information for investments accounted for under the equity method:

	December 31,
	2012		2011
	(In thousands)
Current assets	$	835,997	$	855,962
Noncurrent assets		271,233		211,920
Total Assets	$	1,107,230	$	1,067,882
Current liabilities	$	616,786	$	594,883
Noncurrent liabilities		89,285		112,936
Owners’ equity		401,159		360,063
Total Liabilities and Owners’ Equity	$	1,107,230	$	1,067,882

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
Revenues	$	2,758,159	$	2,669,923	$	2,283,256
Gross profit	$	210,425	$	271,920	$	258,598
Income before provision for income taxes	$	146,911	$	185,859	$	182,482
Provision for income taxes		9,000		14,258		21,230
Net Income	$	137,911	$	171,601	$	161,252

Revenues of equity method investees include $2,222.4 million, $1,956.7 million and $1,605.0 million of reimbursable costs recorded by limited liability companies in our Technical Services segment at December 31, 2012, 2011 and 2010, respectively. Our investment in equity method investees was $4.2 million more than our underlying equity in net assets of those investees based on stated ownership percentages at December 31, 2012. These differences were primarily related to the timing of distribution of dividends and various adjustments under GAAP.

The provision for income taxes is based on the tax laws and rates in the countries in which our investees operate. There is no expected relationship between the provision for income taxes and income before provision for income taxes. The taxation regimes vary not only by their nominal rates, but also by the allowability of deductions, credits and other benefits. For some of our U.S. investees, U.S. income taxes are the responsibility of the respective owners.

Reconciliation of net income per combined income statement information of our investees to equity in income of investees per our consolidated and combined statements of income is as follows:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Equity income based on stated ownership percentages	$	66,064	$	81,971		$	77,882
All other adjustments due to amortization of basis differences, timing of GAAP adjustments and other adjustments		645		(3,316	)		(3,800	)
Equity in income of investees	$	66,709	$	78,655		$	74,082

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Our transactions with unconsolidated affiliates were as follows:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
Sales to	$	42,538	$	49,400	$	45,321
Purchases from	$	1,814	$	980	$	4,693
Dividends received	$	51,594	$	57,801	$	53,633
Capital contributions, net of returns	$	6,289	$	38,176	$	5,412

We recognized a $1.2 million gain in the year ended December 31, 2012 from the sale of our interest in a joint venture associated with the management and operations of the Strategic Petroleum Reserve.

NOTE 4 – INCOME TAXES

B&W and its subsidiaries are subject to U.S. federal income tax and income tax of multiple state and international jurisdictions. We provide for income taxes based on the tax laws and rates in the jurisdictions in which we conduct our operations. These jurisdictions may have regimes of taxation that vary with respect to nominal rates and with respect to the basis on which these rates are applied. This variation, along with the changes in our mix of income within these jurisdictions, can contribute to shifts in our effective tax rate from period to period.

The results of the U.S. operations of MII and/or certain of its subsidiaries were reflected in our consolidated return for U.S. federal income tax purposes and/or certain consolidated, combined and unitary returns for state, local and foreign tax purposes through June 7, 2010. The Statute of Limitations is closed for 2008 and prior tax years.

We are currently under audit by various state and international authorities. With few exceptions, we do not have any returns under examination for years prior to 2008.

We apply the provisions of FASB Topic Income Taxes regarding the treatment of uncertain tax positions. A reconciliation of unrecognized tax benefits follows:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	32,357		$	36,342		$	11,842
Increases based on tax positions taken in the current year		980			1,171			6,550
Increases based on tax positions taken in the prior years		65			3,269			343
Increases due to positions assumed at spin-off		—			—			24,181
Decreases based on tax positions taken in the prior years		(3,114	)		(4,329	)		(1,442	)
Decreases due to settlements with tax authorities		(1,101	)		(1,073	)		(5,132	)
Decreases due to lapse of applicable statute of limitation		(24,700	)		(3,023	)		—
Balance at end of period	$	4,487		$	32,357		$	36,342

The $4.5 million balance of unrecognized tax benefits at December 31, 2012 would reduce our effective tax rate if recognized.

In accordance with FASB Topic Income Taxes, we recognize interest and penalties related to unrecognized tax benefits in our provision for income taxes. During the year ended December 31, 2012, we recorded a reduction in our accruals of $0.8 million, resulting in recorded liabilities of approximately $0.3 million for the payment of tax-related interest and penalties. At December 31, 2011 and 2010, we recorded liabilities of approximately $1.1 million and $4.9 million, respectively, for the payment of tax-related interest and penalties.

We believe that, within the next 12 months, it is reasonably possible that our previously unrecognized tax benefits could decrease by approximately $1.0 million to $3.5 million.

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Deferred income taxes reflect the net tax effects of temporary differences between the financial and tax bases of assets and liabilities. Significant components of deferred tax assets and liabilities as of December 31, 2012 and 2011 were as follows:

	December 31,
	2012			2011
	(In thousands)
Deferred tax assets:
Pension liability	$	201,229		$	216,248
Accrued warranty expense		26,695			33,412
Accrued vacation pay		13,312			13,269
Accrued liabilities for self-insurance (including postretirement health care benefits)		35,374			41,243
Accrued liabilities for executive and employee incentive compensation		39,483			29,539
Environmental and products liabilities		8,024			7,711
Investments in joint ventures and affiliated companies		16,993			3,704
Long-term contracts		29,807			22,871
Net operating loss carryforward		15,787			22,380
State tax net operating loss carryforward		21,757			22,734
Foreign tax credit carryforward		808			18,292
Other		7,722			8,273
Total deferred tax assets		416,991			439,676
Valuation allowance for deferred tax assets		(19,979	)		(9,354	)
Deferred tax assets		397,012			430,322
Deferred tax liabilities:
Property, plant and equipment		39,016			31,874
Investments in joint ventures and affiliated companies		1,064			791
Long-term contracts		30,571			27,681
Intangibles		24,756			26,365
Other		9,580			8,080
Total deferred tax liabilities		104,987			94,791
Net deferred tax assets	$	292,025		$	335,531

Income before provision for income taxes was as follows:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
U.S.	$	222,840	$	39,417	$	174,242
Other than U.S.		96,578		55,081		45,966
Income before provision for income taxes	$	319,418	$	94,498	$	220,208

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The provision for income taxes consisted of:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Current:
U.S. – federal	$	39,784	$	24,591		$	29,191
U.S. – state and local		7,979		7,452			8,029
Other than U.S.		11,060		11,037			11,617
Total current		58,823		43,080			48,837
Deferred:
U.S. – Federal		24,560		(20,066	)		33,541
U.S. – State and local		6,545		5,195			(389	)
Other than U.S.		11,933		(4,329	)		(1,984	)
Total deferred (benefit) provision		43,038		(19,200	)		31,168
Provision for income taxes	$	101,861	$	23,880		$	80,005

The following is a reconciliation of the U.S. statutory federal tax rate (35%) to the consolidated and combined effective tax rate:

	Year Ended December 31,
	2012			2011			2010
U.S. federal statutory (benefit) rate		35.0	%		35.0	%		35.0	%
State and local income taxes		4.3			6.4			3.4
Foreign rate differential		(4.1	)		(11.8	)		(5.3	)
Foreign operations		0.5			6.4			0.4
Tax credits		(2.5	)		(46.8	)		(4.9	)
Dividends and deemed dividends from affiliates		2.3			38.7			9.1
Valuation allowances		3.4			7.6			(2.6	)
Uncertain tax positions		(9.0	)		(2.8	)		1.3
Non-deductible expenses		1.3			5.5			1.1
Additional spin related benefit		—			(4.6	)		—
Manufacturing deduction		(1.3	)		(3.6	)		(1.6	)
Minority interest		1.1			3.2			—
Other		0.9			(7.9	)		0.4
Effective tax rate		31.9	%		25.3	%		36.3	%

At December 31, 2012, we had a valuation allowance of $20.0 million for deferred tax assets, which we expect cannot be realized through carrybacks, future reversals of existing taxable temporary differences and our estimate of future taxable income. We believe that our remaining deferred tax assets are more likely than not realizable through carrybacks, future reversals of existing taxable temporary differences and our estimate of future taxable income. Any changes to our estimated valuation allowance could be material to our consolidated financial statements.

The following is an analysis of our valuation allowance for deferred tax assets:

	Beginning Balance			Charges To Costs and Expenses			Charged To Other Accounts		Effect Of Spin-Off(1)		Ending Balance
	(In thousands)
Year Ended December 31, 2012	$	(9,354	)		(10,625	)		—		—	$	(19,979	)
Year Ended December 31, 2011	$	(2,205	)		(7,149	)		—		—	$	(9,354	)
Year Ended December 31, 2010	$	(28,701	)		6,904			—		19,592	$	(2,205	)

⁽¹⁾  Effect of spin-off includes state tax valuation allowances distributed to MII in the spin-off.

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We have foreign net operating loss carryforwards of $64.4 million available to offset future taxable income in foreign jurisdictions. Of the foreign net operating loss carryforwards, $3.1 million is scheduled to expire in 2015 to 2032. The foreign net operating losses have a valuation allowance of $0.9 million against the related deferred taxes. In addition, we have foreign tax credit carryovers of $0.8 million which will expire in 2013. We have state net operating losses of $408.5 million available to offset future taxable income in various states. Our state net operating loss carryforwards begin to expire in the year 2013. We are carrying a valuation allowance of $9.5 million against the deferred tax asset related to the state loss carryforwards.

We would be subject to withholding taxes if we were to distribute earnings from certain foreign subsidiaries. For the year ended December 31, 2012, the undistributed earnings of these subsidiaries were $271.1 million. Unrecognized deferred income tax liabilities, including withholding taxes, of approximately $20.0 million would be payable upon distribution of these earnings. We have provided tax of $2.0 million on earnings we intend to remit. All other earnings are considered permanently reinvested.

The American Taxpayer Relief Act of 2012 was signed into law on January 2, 2013. Some provisions of this law provide for retroactive changes to the 2012 tax year which we did not consider in determining our effective tax rate for 2012. The impact of these retroactive changes will be recorded in the first quarter of 2013.

NOTE 5 – LONG-TERM DEBT AND NOTES PAYABLE

	December 31,
	2012			2011
	(In thousands)
Long-term debt consists of:
Secured Debt:
Power Generation – various notes payable	$	639		$	831
Other		5			7
		644			838
Less: Amounts due within one year		214			205
Long-term debt	$	430		$	633
Notes payable and current maturities of long-term debt consist of:
Short-term lines of credit	$	3,848		$	4,448
Current maturities of long-term debt		214			205
Total	$	4,062		$	4,653
Interest rate on short-term borrowing		6.6	%		7.2	%

Our short-term lines of credit represent borrowings by one of our subsidiaries. We have included this amount in notes payable and current maturities of long-term debt on our consolidated balance sheets. This facility is renewable annually and the interest rate associated with this line of credit was 6.6% per annum at December 31, 2012.

Maturities of long-term debt during the five years subsequent to December 31, 2012 are as follows: 2013 – $0.2 million; 2014 – $0.2 million; 2015 – $0.2 million; 2016 – $0.0 million; and 2017 – $0.0 million.

Credit Facility

On June 8, 2012, B&W entered into an Amended and Restated Credit Agreement (the “Credit Agreement”) with a syndicate of lenders and letter of credit issuers, and Bank of America, N.A., as administrative agent, which amends and restates our previous Credit Agreement dated May 3, 2010. The Credit Agreement provides for revolving credit borrowings and issuances of letters of credit in an aggregate outstanding amount of up to $700 million, and is scheduled to mature June 8, 2017. The proceeds of the Credit Agreement are available for working capital needs and other general corporate purposes. The Credit Agreement includes procedures for additional financial institutions to become lenders, or for any existing lender to increase its commitment thereunder, subject to an aggregate maximum of $1.0 billion for all revolving loan and letter of credit commitments.

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The Credit Agreement is guaranteed by substantially all of B&W’s wholly owned domestic subsidiaries. Obligations under the Credit Agreement are secured by first-priority liens on certain assets owned by B&W and the guarantors (other than subsidiaries comprising our Nuclear Operations and Technical Services segments). If the corporate family rating of B&W and its subsidiaries from Moody’s is Baa3 or better (with a stable outlook or better), the corporate rating of B&W and its subsidiaries from S&P is BBB- or better (with a stable outlook or better), and other conditions are met, the liens securing obligations under the Credit Agreement will be released, subject to reinstatement upon the terms set forth in the Credit Agreement.

The Credit Agreement requires only interest payments on a periodic basis until maturity. We may prepay all loans under the Credit Agreement at any time without premium or penalty (other than customary LIBOR breakage costs), subject to certain notice requirements.

The Credit Agreement contains financial covenants relating to leverage and interest coverage and includes covenants that restrict, among other things, the level of debt incurrence, liens, investments, acquisitions, asset dispositions, dividends, prepayments of subordinated debt and mergers. At December 31, 2012, we were in compliance with all of the covenants set forth in the Credit Agreement. A comparison of the key financial covenants and current compliance at December 31, 2012 is as follows:

	Required	Actual
Maximum leverage ratio	Less than 2.75 to 1.0		0.06 to 1.0
Minimum interest coverage ratio	Greater than 4.0 to1.0		78.13 to 1.0

Loans outstanding under the Credit Agreement bear interest at our option at either the Eurocurrency rate plus a margin ranging from 1.25% to 2.25% per year or the base rate (the highest of the Federal Funds rate plus 0.50%, the one month Eurocurrency rate plus 1.0%, or the administrative agent’s prime rate) plus a margin ranging from 0.25% to 1.25% per year. The applicable margin for revolving loans varies depending on the credit ratings of the Credit Agreement. Under the Credit Agreement, we are charged a commitment fee on the unused portions of the Credit Agreement and that fee varies between 0.225% and 0.350% per year depending on the credit ratings of the Credit Agreement. Additionally, we are charged a letter of credit fee of between 1.25% and 2.25% per year with respect to the amount of each financial letter of credit issued under the Credit Agreement and a letter of credit fee of between 0.80% and 1.25% per year with respect to the amount of each performance letter of credit issued under the Credit Agreement, in each case depending on the credit ratings of the Credit Agreement. We also pay customary fronting fees and other fees and expenses in connection with the issuance of letters of credit under the Credit Agreement. In connection with entering into the Credit Agreement, we paid upfront fees to the lenders thereunder, and arrangement and other fees to the arrangers and agents of the Credit Agreement. At December 31, 2012, there were no borrowings outstanding and letters of credit issued under the Credit Agreement totaled $157.9 million, resulting in $542.1 million available for borrowings or to meet letter of credit requirements. The applicable interest rate at December 31, 2012 under this facility was 3.75% per year for revolving loans.

Based on the current credit ratings of the Credit Agreement, the applicable margin for Eurocurrency loans is 1.50%, the applicable margin for base rate loans is 0.50%, the letter of credit fee for financial letters of credit is 1.50%, the letter of credit fee for performance letters of credit is 0.875%, and the commitment fee for unused portions of the Credit Agreement is 0.25%. The Credit Agreement does not have a floor for the base rate or the Eurocurrency rate.

The Credit Agreement generally includes customary events of default for a secured credit facility. If any default occurs under the Credit Agreement, or if we are unable to make any of the representations and warranties in the Credit Agreement, we will be unable to borrow funds or have letters of credit issued under the Credit Agreement.

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Other Arrangements

Certain foreign subsidiaries in our Power Generation segment have credit arrangements with various commercial banks and other financial institutions for the issuance of bank guarantees in association with contracting activity. The aggregate value of all such bank guarantees as of December 31, 2012 was $59.4 million.

B&W and certain of its subsidiaries have jointly executed general agreements of indemnity in favor of surety underwriters relating to surety bonds those underwriters issue in support of some of our contracting activity. As of December 31, 2012, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $468.6 million.

NOTE 6 – PENSION PLANS AND POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits, primarily through noncontributory pension plans, for most of our regular employees. As of 2006, our retirement plans for U.S.-based employees were closed to new entrants for our corporate employees and were closed to new salaried plan entrants for our existing plans within our Power Generation and Nuclear Operations segments. Effective October 31, 2008, the salaried and hourly retirement plans acquired with Marine Mechanical Corporation were merged into the retirement plan for our Nuclear Operations segment. Effective December 31, 2008, we acquired the retirement plans and postretirement benefit plans of NFS.

We do not provide retirement benefits to certain non-resident alien employees of foreign subsidiaries. Retirement benefits for salaried employees who accrue benefits in a defined benefit plan are based on final average compensation and years of service, while benefits for hourly paid employees are based on a flat benefit rate and years of service. Our funding policy is to fund the plans as recommended by the respective plan actuaries and in accordance with the Employee Retirement Income Security Act of 1974, as amended, or other applicable law. The Pension Protection Act of 2006 became effective in 2008. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued. Assuming we continue as a government contractor, our contractual arrangements with the U.S. Government provide for the recovery of contributions to our pension and other postretirement benefit plans covering employees working primarily in our Nuclear Operations segment.

In October 2012, we notified employees that, effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under our major U.S. and Canadian defined benefit qualified pension plans will cease. This amendment is reflected as a curtailment at December 31, 2012. Furthermore, effective January 1, 2016, we will make service-based, cash contributions to The Babcock & Wilcox Company Thrift Plan (“Thrift Plan”) for those employees impacted by the plan freeze.

Effective January 1, 2012, a defined contribution component was adopted applicable to Babcock & Wilcox Canada, Ltd. (the “Canadian Plans”). Any employee with less than two years of continuous service as of December 31, 2011 was required to enroll in the defined contribution component of the Canadian Plans as of January 1, 2012 or upon the completion of six months of continuous service, whichever is later. These and future employees will not be eligible to enroll in the defined benefit component of the Canadian Plans. This amendment to the Canadian Plans is reflected as a curtailment at December 31, 2012.

Prior to the spin-off, the combined statements included the pension liability of the Retirement Plan for Employees of McDermott Incorporated and Participating Subsidiary and Affiliated Companies (the “MI Plan”). In connection with the spin-off, the majority of the MI Plan pension liability, along with the subsidiary holding this liability, was transferred to MII.

We make available other benefits which include postretirement health care and life insurance benefits to certain salaried and union retirees based on their union contracts. Certain subsidiaries provide these benefits to unionized and salaried future retirees.

As described in Note 1, we elected to change our accounting method for recognizing actuarial gains and losses for our pension and other postretirement benefit plans. Accordingly, we have made revisions to previously disclosed amounts, specifically net periodic benefit cost and accumulated other comprehensive income, where certain amounts have been reclassified to retained earnings.

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Obligations and Funded Status

	Pension Benefits Year Ended December 31,						Other Benefits Year Ended December 31,
	2012			2011			2012			2011
	(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of period	$	2,687,007		$	2,479,783		$	122,460		$	125,692
Service cost		46,828			43,495			1,138			1,143
Interest cost		122,605			134,927			5,124			5,805
Plan participants’ contributions		300			318			115			116
Curtailments		(94,642	)		—			—			—
Amendments		2,996			2,055			(1,302	)		(1,351	)
Settlements		(57,430	)		(13,625	)		—			—
Actuarial loss (gain)		198,935			181,517			(2,153	)		1,491
Foreign currency exchange rate changes		6,793			(5,633	)		220			(211	)
Benefits paid		(133,402	)		(135,830	)		(9,346	)		(10,225	)
Benefit obligation at end of period	$	2,779,990		$	2,687,007		$	116,256		$	122,460
Change in plan assets:
Fair value of plan assets at beginning of period	$	1,917,850		$	1,782,048		$	33,558		$	33,389
Actual return on plan assets		207,728			115,787			2,233			723
Plan participants’ contributions		300			318			115			116
Company contributions		187,284			174,639			10,764			9,555
Settlements		(57,430	)		(13,625	)		—			—
Foreign currency exchange rate changes		5,364			(5,487	)		—			—
Benefits paid		(133,402	)		(135,830	)		(9,346	)		(10,225	)
Fair value of plan assets at the end of period		2,127,694			1,917,850			37,324			33,558
Funded status	$	(652,296	)	$	(769,157	)	$	(78,932	)	$	(88,902	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(75,119	)	$	(185,832	)	$	(7,724	)	$	(8,239	)
Accumulated postretirement benefit obligation		—			—			(71,208	)		(80,663	)
Pension liability		(577,177	)		(583,337	)		—			—
Prepaid pension		—			12			—			—
Accrued benefit liability, net	$	(652,296	)	$	(769,157	)	$	(78,932	)	$	(88,902	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	18,327		$	19,949		$	(2,523	)	$	(1,360	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	2,779,990		$	2,686,796			N/A			N/A
Accumulated benefit obligation	$	2,723.930		$	2,515,868		$	116,256		$	122,460
Fair value of plan assets	$	2,127,694		$	1,917,626		$	37,324		$	33,558
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	211			N/A			N/A
Accumulated benefit obligation	$	—		$	211		$	—		$	—
Fair value of plan assets	$	—		$	224		$	—		$	—

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	Pension Benefits Year Ended December 31,									Other Benefits Year Ended December 31,
	2012			2011			2010			2012			2011			2010
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	46,828		$	43,495		$	39,176		$	1,138		$	1,143		$	1,069
Interest cost		122,605			134,927			142,092			5,124			5,805			7,284
Expected return on plan assets		(136,913	)		(148,347	)		(136,364	)		(1,930	)		(1,919	)		(1,744	)
Amortization of prior service cost		3,579			3,721			3,711			(139	)		33			28
Recognized net actuarial loss (gain)		34,496			212,802			106,805			(2,456	)		2,952			(14,997	)
Net periodic benefit cost (income)	$	70,595		$	246,598		$	155,420		$	1,737		$	8,014		$	(8,360	)

Recognized net actuarial loss (gain) consists primarily of our reported actuarial loss (gain), curtailments, and the difference between the actual return on plan assets and the expected return on plan assets. These amounts are disclosed in this Note 6. As discussed in Note 17, we have excluded the recognized net actuarial loss (gain) from our reportable segments and such amount has been reflected in Note 17 as the Mark to Market Adjustment in the reconciliation of reportable segment income to consolidated operating income.

Additional Information

	Pension Benefits Year Ended December 31,						Other Benefits Year Ended December 31,
	2012			2011			2012		2011
	(In thousands)
Increase (decrease) in accumulated other comprehensive income due to actuarial losses—before taxes	$	(1,957	)	$	(3,258	)	$	1,302	$	1,616

In the current fiscal year, we have recognized expense (income) in other comprehensive income as components of net periodic benefit cost approximately $3.6 million and $(0.1) million for our pension benefits and other benefits, respectively. In the next fiscal year, we expect to recognize expense (income) in other comprehensive income as components of net periodic benefit cost approximately $3.7 million and $(0.3) million for our pension benefits and other benefits, respectively.

Assumptions

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate		4.09	%		4.76	%		3.43	%		4.35	%
Rate of compensation increase		2.57	%		3.69	%		—			—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate		4.76	%		5.56	%		4.34	%		4.92	%
Expected return on plan assets		7.08	%		8.24	%		5.76	%		5.76	%
Rate of compensation increase		3.69	%		3.69	%		—			—

The expected rate of return on plan assets assumption is based on the long-term expected returns for the investment mix of assets currently in the portfolio. In setting this rate, we use a building-block approach. Historic real return trends for the various asset classes in the plan’s portfolio are combined with anticipated future market conditions to estimate the real rate of return for each class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each class. The expected rate of return on plan assets is determined to be the weighted average of the nominal returns based on the weightings of the classes within the total asset portfolio. We are using an expected return on plan assets assumption of 7.2% for the majority of our existing pension plan assets (approximately 89% of our total pension assets at December 31, 2012).

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Our existing other benefit plans are unfunded, with the exception of the NFS postretirement benefit plans. These plans provide health benefits to certain salaried and hourly employees, as well as retired employees, of NFS. Approximately 85% of total assets for these postretirement benefit plans are contributed into a Voluntary Employees’ Beneficiary Association trust.

	2012			2011
Assumed health-care cost trend rates at December 31
Health-care cost trend rate assumed for next year		8.50	%		8.00	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)		4.50	%		4.50	%
Year that the rate reaches ultimate trend rate		2021			2019

Assumed health-care cost trend rates have a significant effect on the amounts we report for our health-care plan. A one-percentage-point change in our assumed health-care cost trend rates would have the following effects:

	One-Percentage- Point Increase		One-Percentage- Point Decrease
	(In thousands)
Effect on total of service and interest cost	$	475	$	(401	)
Effect on postretirement benefit obligation	$	7,756	$	(6,456	)

Investment Goals

General

The overall investment strategy of the pension trusts is to achieve long-term growth of principal, while avoiding excessive risk and to minimize the probability of loss of principal over the long term. The specific investment goals that have been set for the pension trusts in the aggregate are (1) to ensure that plan liabilities are met when due and (2) to achieve an investment return on trust assets consistent with a reasonable level of risk.

Allocations to each asset class for both domestic and foreign plans are reviewed periodically and rebalanced, if appropriate, to assure the continued relevance of the goals, objectives and strategies. The pension trusts for both our domestic and foreign plans employ a professional investment advisor and a number of professional investment managers whose individual benchmarks are, in the aggregate, consistent with the plan’s overall investment objectives. The goals of each investment manager are (1) to meet (in the case of passive accounts) or exceed (for actively managed accounts) the benchmark selected and agreed upon by the manager and the Trust and (2) to display an overall level of risk in its portfolio that is consistent with the risk associated with the agreed upon benchmark.

The investment performance of total portfolios, as well as asset class components, is periodically measured against commonly accepted benchmarks, including the individual investment manager benchmarks. In evaluating investment manager performance, consideration is also given to personnel, strategy, research capabilities, organizational and business matters, adherence to discipline and other qualitative factors that may impact the ability to achieve desired investment results.

Domestic Plans

We sponsor the following domestic defined benefit plans:

• Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (covering Power Generation and Nuclear Energy segment employees);

• Retirement Plan for Employees of Babcock & Wilcox Governmental Operations (covering Nuclear Operations and Technical Services segment employees and Corporate employees);

• Nuclear Fuel Services, Inc. Retirement Plan for Salaried Employees; and

• Nuclear Fuel Services, Inc. Retirement Plan for Hourly Employees.

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The assets of the domestic pension plans are commingled for investment purposes and held by the Trustee, The Bank of New York Mellon, in The Babcock & Wilcox Company Master Trust (the “Master Trust”). For the years ended December 31, 2012 and 2011, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 12% and 7%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2012 and 2011 by asset category:

	2012			2011
Asset Category:
Commingled and Mutual Funds		34	%		25	%
Fixed Income (excluding U. S. Government Securities)		29	%		27	%
U.S. Government Securities		22	%		18	%
Equity Securities		6	%		17	%
Partnerships with Security Holdings		6	%		8	%
Real Estate		1	%		3	%
Other		2	%		2	%
Total		100	%		100	%

The target allocation for 2013 for the domestic plans, by asset class, is as follows:

Asset Class:
Fixed Income	55	%
Equities	45	%

Foreign Plans

We sponsor various plans through certain of our foreign subsidiaries. These plans are the Canadian Plans and the Diamond Power Specialty Limited Retirement Benefits Plan (the “Diamond UK Plan”).

The combined weighted average asset allocations of these plans at December 31, 2012 and 2011 by asset category were as follows:

	2012			2011
Asset Category:
Equity Securities and Commingled Mutual Funds		58	%		56	%
Fixed Income		40	%		41	%
Other		2	%		3	%
Total		100	%		100	%

The target allocation for 2013 for the foreign plans, by asset class, is as follows:

	Canadian Plans			Diamond UK Plan
Asset Class:
U. S. Equity		17	%		9	%
Global Equity		38	%		46	%
Fixed Income		45	%		45	%

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Fair Value

See Note 16 for a detailed description of fair value measurements and the hierarchy established for valuation inputs. The following is a summary of total investments for our plans measured at fair value at December 31, 2012:

	12/31/12		Level 1		Level 2		Level 3
	(In thousands)
Pension and Other Benefits:
Fixed Income	$	649,978	$	1,031	$	648,947	$	—
Equities		120,223		120,220		—		3
Commingled and Mutual Funds		791,195		9,084		782,111		—
U.S. Government Securities		425,709		425,709		—		—
Partnerships with Security Holdings		112,881		—		—		112,881
Real Estate		14,516		—		—		14,516
Cash and Accrued Items		50,516		46,785		3,731		—
Total Assets	$	2,165,018	$	602,829	$	1,434,789	$	127,400

The following is a summary of total investments for our plans measured at fair value at December 31, 2011:

	12/31/11		Level 1		Level 2		Level 3
	(In thousands)
Pension and Other Benefits:
Fixed Income	$	550,146	$	—	$	550,146	$	—
Equities		298,083		298,077		—		6
Commingled and Mutual Funds		546,776		8,250		538,526		—
U.S. Government Securities		313,458		313,458		—		—
Partnerships with Security Holdings		134,295		—		—		134,295
Real Estate		53,560		—		—		53,560
Cash and Accrued Items		55,090		54,970		120		—
Total Assets	$	1,951,408	$	674,755	$	1,088,792	$	187,861

The following is a summary of the changes in the Plans’ Level 3 instruments measured on a recurring basis for the years ended December 31, 2012 and 2011:

	Year ended December 31,
	2012			2011
	(In thousands)
Balance at beginning of period	$	187,861		$	207,244
Issuances and acquisitions		12,593			16,821
Dispositions		(74,329	)		(52,572	)
Realized gain		692			5,897
Unrealized gain		583			10,471
Balance at end of period	$	127,400		$	187,861

Our Level 3 instruments include assets with no market price but rather calculations of net asset values per share or its equivalent. When appropriate, we adjust these net asset values for contributions and distributions, if any, made during the period beginning on the latest net asset value valuation date and ending on our measurement date. We also consider available market data, relevant index returns, preliminary estimates from our investees and other data obtained through research and consultation with third party advisors in determining the fair value of our Level 3 instruments.

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Cash Flows

	Domestic Plans				Foreign Plans
	Pension Benefits		Other Benefits		Pension Benefits		Other Benefits
	(In thousands)
Expected employer contributions to trusts of defined benefit plans:
2013	$	52,000	$	2,082	$	20,040		N/A
Expected benefit payments:
2013		127,558		12,500		11,389		596
2014		133,785		11,768		12,075		621
2015		139,444		10,581		12,731		613
2016		144,617		9,470		13,671		598
2017		149,047		8,163		14,116		618
2018-2022		785,955		28,708		79,572		3,315

The expected employer contributions to trusts for 2013 are included in current liabilities at December 31, 2012.

Defined Contribution Plans

We provide benefits under The Babcock & Wilcox Company Supplemental Executive Retirement Plan (“SERP Plan”), which is a defined contribution plan. Prior to the spin-off, we participated in the McDermott International, Inc. SERP Plan. We recorded expense related to the SERP Plan of approximately $0.6 million, $0.3 million and $0.7 million in the years ended December 31, 2012, 2011 and 2010, respectively.

We also provide benefits under the Thrift Plan. The Thrift Plan generally provides for matching employer contributions of 50% of participants’ contributions up to 6 percent of compensation. These matching employer contributions are typically made in shares of BWC common stock. Prior to the spin-off, we participated in the Thrift Plan for Employees of McDermott Incorporated and Participating Subsidiary and Affiliated Companies (“MI Thrift Plan”). The MI Thrift Plan also provided for matching employer contributions of 50% of participants’ contributions up to 6 percent of compensation and employer contributions were typically made in shares of MII common stock. We also provide service-based cash contributions under the Thrift Plan to employees not accruing benefits under our defined benefit plans. Amounts charged to expense for employer contributions under the Thrift Plan and MI Thrift Plan totaled approximately $24.2 million, $22.1 million and $19.7 million in the years ended December 31, 2012, 2011 and 2010, respectively.

Effective January 1, 2012, we adopted The Babcock & Wilcox Company Defined Contribution Restoration Plan (the “Restoration Plan”) to restore benefits that would be provided to participants in the Thrift Plan but are precluded by the application of certain sections of the Internal Revenue Code of 1986, as amended (the “Code”). Each participant who is precluded from receiving the full amount of service-based contributions otherwise provided under the Thrift Plan in a plan year by the application of Code Section 401(a)(17) or 415(c) shall be credited with a employer service-based contribution for such plan year equal to the excess of the amount of service-based contributions that would have been made to the participant’s Thrift Plan account without the application of Code Section 401(a)(17) and 415(c) for the plan year over the amount of service-based contribution actually made to such Participant’s Thrift Plan account for the plan year. In addition, the Restoration Plan permits participants who are precluded from making the full amount of employee contributions to the Thrift Plan and receiving associated employer matching contributions by the application of Code Sections 401(a)(17) and 415(c) to elect to make deferral contributions and receive associated employer matching contributions under the Restoration Plan. Amounts charged to expense under the Restoration Plan totaled approximately $0.1 million in the year ended December 31, 2012.

Effective January 1, 2012, a defined contribution component was added to those Canadian Plans previously offering defined benefits to salaried employees. As of January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for employer contributions was approximately $0.5 million in the year ended December 31, 2012.

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Multiemployer Plans

One of our subsidiaries in the Power Generation segment contributes to various multiemployer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. Effective December 31, 2011, we adopted the disclosure provisions pertaining to these benefits that were issued in September, 2011 under FASB subtopic Compensation—Retirement Benefits—Multiemployer Plans.

The following table summarizes our contributions to multiemployer plans for the years covered by this report:

		Pension Protection										Expiration Date
		Act Zone		FIP/RP Status	Contributions							Of Collective
		Zone Status		Pending/	2012		2011		2010		Surcharge	Bargaining
Pension Fund	EIN/PIN	2012	2011	Implemented	(in millions)						Imposed	Agreement
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	18.9	$	25.9	$	12.4	No	Described Below
All Other						5.3		5.5		6.0
					$	24.2	$	31.4	$	18.4

The Boilermaker-Blacksmith National Pension Trust (the “Boilermaker Plan”) is, by plan, the only significant contribution of our total contributions to these funds. Our collective bargaining agreements with the Boilermaker Plan are under a National Maintenance Agreement platform which is evergreen in terms of expiration. However, the agreement allows for termination by either party with a 90-day written notice. Our contributions to the Boilermaker Plan constitute less than 5% of total contributions to the plan. All other contributions expense for all periods included in this report represents multiple amounts to various plans that, individually, are deemed to be insignificant.

NOTE 7—ASSET SALES AND IMPAIRMENT OF LONG-LIVED ASSETS

We had net gains on asset sales of approximately $3.1 million during the year ended December 31, 2011, primarily attributable to the sale of a wholly owned manufacturing facility in a Chinese subsidiary of Babcock & Wilcox Power Generation Group, Inc. (“B&W PGG”).

During the years ended December 31, 2012, 2011 and 2010, we did not record any impairments of property, plant and equipment.

NOTE 8—CAPITAL STOCK

B&W was a wholly owned subsidiary of MII, until July 30, 2010 when MII distributed 100% of our outstanding common stock to the MII shareholders. On July 2, 2010, MII’s Board of Directors approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of MII common stock. The distribution of B&W common stock was made on July 30, 2010, and consisted of one share of B&W common stock for every two shares of MII common stock to holders of MII common stock. On July 30, 2010, 116,225,732 shares of our common stock were distributed to MII shareholders to complete our spin-off from MII.

On November 5, 2012, our board of directors declared a dividend of $0.08 per share payable on December 17, 2012 to shareholders of record on November 19, 2012. In addition, our board authorized us to repurchase an indeterminate number of shares of our common stock at an aggregate value of up to $250 million. We may repurchase shares from time to time during a two-year period in the open market. As of December 31, 2012, we have repurchased 3,908,684 shares of common stock for approximately $96.7 million. On February 8, 2013, our board of directors declared a dividend of $0.08 per share payable on March 12, 2013 to shareholders of record on February 19, 2013.

We issue shares of our common stock in connection with our 2010 Long-Term Incentive Plan, and contributions to our Thrift Plan. At December 31, 2012, 9,111,185 shares of common stock were reserved for issuance in connection with those plans.

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NOTE 9—STOCK-BASED COMPENSATION

2010 Long-Term Incentive Plan of The Babcock & Wilcox Company

We established the 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (the “Plan”). Members of the Board of Directors, executive officers, key employees and consultants are eligible to participate in the Plan. The Compensation Committee of the Board of Directors selects the participants for the Plan. The Plan provides for a number of forms of stock-based compensation, including incentive and non-qualified stock options, restricted stock, restricted stock units and performance shares and performance units, subject to satisfaction of specific performance goals. Shares subject to awards under the Plan that are cancelled, forfeited, terminated or expire unexercised, shall immediately become available for the granting of awards under this Plan. In addition, 10,000,000 shares were authorized for issuance through the Plan. Options to purchase shares are granted at not less than 100% of the fair market value closing price on the date of grant, become exercisable at such time or times as determined when granted and expire not more than seven years after the date of grant.

At December 31, 2012, we had awarded 4,610,485 shares under this plan, and had a total of 5,389,515 shares of our common stock available for future awards. In the event of a change in control of our company, the terms of the awards under the Plan contain provisions that may cause restrictions to lapse and accelerate the vesting of plan awards.

2012 Long-Term Incentive Plan of Babcock & Wilcox Technical Services Group, Inc.

In June 2012, we established the 2012 Long-Term Incentive Plan of Babcock & Wilcox Technical Services Group, Inc., a cash-settled plan for employees of certain subsidiaries and unconsolidated affiliates as selected by the plan committee. The cash-settled plan provides for a number of forms of stock-based compensation, including stock appreciation rights, restricted stock units and performance units, subject to satisfaction of specific performance goals. Stock appreciation rights are granted at not less than 100% of the fair market value closing price of a share of B&W common stock on the date of grant, become exercisable at such time or times as determined when granted and expire not more than seven years after the date of grant. Stock appreciation rights are cash settled for the excess of the market price of B&W common stock on the exercise date minus the exercise price. Restricted stock units and performance units are cash settled upon vesting as determined when granted. We will not issue any shares of B&W common stock under this plan, as all awards are cash settled.

In the event of a change in control of our company, the terms of the awards under the cash-settled plan contain provisions that may cause restrictions to lapse and accelerate the vesting of plan awards.

Total stock-based compensation expense for all of our plans recognized for the years ended December 31, 2012, 2011 and 2010 totaled $18.3 million, $17.9 million and $16.3 million, respectively, with associated tax benefit recognized for the years ended December 31, 2012, 2011 and 2010 totaling $6.9 million, $6.6 million and $6.0 million, respectively.

Prior to August 1, 2010, all of our stock-based compensation expense was attributable to our participation in MII legacy stock-based compensation plans. Expense recognized prior to August 1, 2010 was based on the fair value of MII’s stock-based compensation awards. For the five month period August 1, 2010 to December 31, 2010, stock-based compensation expense attributable to the Plan totaled $4.4 million, net of tax benefits totaling $2.6 million.

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As of December 31, 2012, total unrecognized estimated compensation expense related to nonvested awards was $15.6 million, net of estimated tax benefits of $9.5 million. The total gross unrecognized estimated compensation expense of $25.1 million is expected to be recognized over a weighted-average period of 1.9 years.

B&W Stock Options

The fair value of each option grant was estimated at the date of grant using Black-Scholes, with the following weighted-average assumptions:

	Year Ended December 31,
	2012			2011			2010
Risk-free interest rate		0.65	%		1.52	%		1.28	%
Expected volatility		.36			.46			.61
Expected life of the option in years		3.98			3.75			4.08
Expected dividend yield		0	%		0	%		0	%

The risk-free interest rate is based on the implied yield on a U.S. Treasury zero-coupon issue with a remaining term equal to the expected life of the option. The expected volatility is based on implied volatility from publicly traded options on our common stock, historical volatility of the price of our common stock and other factors. The expected life of the option is based on observed historical patterns. The expected dividend yield is based on the projected annual dividend payment per share divided by the stock price at the date of grant. This amount was zero because we did not expect to pay dividends at the grant dates for the stock options awarded.

The following table summarizes activity for our stock options for the year ended December 31, 2012 (share data in thousands):

	Number of Shares			Weighted- Average Exercise Price		Weighted- Average Remaining Contractual Term		Aggregate Intrinsic Value (in  millions)
Outstanding at beginning of period		1,154		$	22.68
Granted		711			25.96
Exercised		(262	)		11.24
Cancelled/expired/forfeited		(171	)		29.05
Outstanding at end of period		1,432		$	25.65		5.2 Years	$	4.2
Exercisable at end of period		536		$	22.31		4.1 Years	$	3.5

The aggregate intrinsic value included in the table above represents the total pretax intrinsic value that would have been received by the option holders had all option holders exercised their options on December 31, 2012. The intrinsic value is calculated as the total number of option shares multiplied by the difference between the closing price of our common stock on the last trading day of the period and the exercise price of the options. This amount changes based on the price of our common stock.

The weighted-average fair value of the stock options granted in the years ended December 31, 2012, 2011 and 2010 was $7.30, $12.33 and $10.64, respectively.

During the years ended December 31, 2012, 2011 and 2010, the total intrinsic value of stock options exercised was $3.8 million, $7.5 million and $1.5 million, respectively. The actual tax benefits realized related to the stock options exercised during the year ended December 31, 2012 were $0.6 million.

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B&W Restricted Stock

Nonvested restricted stock awards as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (share data in thousands):

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		13		$	20.58
Granted		—			—
Vested		(7	)		19.04
Cancelled/forfeited		—			—
Nonvested at end of period		6		$	22.39

B&W Performance Shares

Nonvested performance shares as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (share data in thousands):

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		477		$	33.56
Granted		493			26.09
Vested		—			—
Cancelled/forfeited		(171	)		30.77
Nonvested at end of period		799		$	29.55

The actual number of shares in which each participant vests is dependent upon achievement of certain Return on Invested Capital and Diluted Earnings Per Share targets over three-year performance periods. The number of shares in which participants can vest ranges from zero to 200% of the initial performance shares granted, to be determined upon completion of the three-year performance period. The number of shares included in the table above assumes the nonvested awards at the beginning of the period will vest at 180% of the target shares and awards granted during 2012 will vest at 100% of the target shares.

B&W Restricted Stock Units

Nonvested restricted stock units as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (share data in thousands):

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		491		$	22.25
Granted		365			25.53
Vested		(357	)		19.31
Cancelled/forfeited		(78	)		27.69
Nonvested at end of period		421		$	26.58

The actual tax benefits realized related to the restricted stock units vested during the year ended December 31, 2012 were $1.0 million.

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Cash-Settled Stock Appreciation Rights

The fair value of each stock appreciation right grant was calculated at the grant date using Black-Scholes and was remeasured at the end of the reporting period with the following weighted-average assumptions:

	Year Ended December 31, 2012
Risk-free interest rate		0.50	%
Expected volatility		0.32
Expected life of the option in years		3.55
Expected dividend yield		1.23	%

The risk-free interest rate is based on the implied yield on a U.S. Treasury zero-coupon issue with a remaining term equal to the expected life of the stock appreciation right. The expected volatility is based on implied volatility from publicly traded options on our common stock, historical volatility of the price of our common stock and other factors. The expected life of the stock appreciation right is based on observed historical patterns and the length of time each award has been outstanding as of each measurement date. The expected dividend yield is based on the projected annual dividend payment per share divided by the stock price at the date of measurement.

The following table summarizes activity for our stock appreciation rights for the year ended December 31, 2012 (unit data in thousands):

	Number of Units			Weighted- Average Exercise Price		Weighted- Average Remaining Contractual Term		Aggregate Intrinsic Value (in  millions)
Outstanding at beginning of period		—		$	—
Granted		49			25.23
Exercised		—			—
Cancelled/expired/forfeited		(12	)		25.11
Outstanding at end of period		37		$	25.27		6.5 Years	$	0.0
Exercisable at end of period		—		$	—		—	$	—

The aggregate intrinsic value included in the table above represents the total pretax intrinsic value that would have been received by the stock appreciation rights holders had all holders exercised their rights on December 31, 2012. The intrinsic value is calculated as the total number of stock appreciation rights multiplied by the difference between the closing price of our common stock on the last trading day of the period and the exercise price of the stock appreciation rights. This amount changes based on the price of our common stock.

The weighted-average fair value as of December 31, 2012 for stock appreciation rights granted for the year ended December 31, 2012 was $5.96. This fair value is re-determined at the end of each reporting period for purposes of remeasuring compensation expense associated with these cash-settled awards.

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Cash-Settled Performance Units

Nonvested cash-settled performance units as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (unit data in thousands):

	Number of Units			Weighted- Average Fair  Value
Nonvested at beginning of period		—
Granted		40
Vested		—
Cancelled/forfeited		(10	)
Nonvested at end of period		30		$	26.20

The actual number of units in which each participant vests is dependent upon achievement of certain Return on Invested Capital and Diluted Earnings Per Share targets over three-year performance periods. The number of units in which participants can vest ranges from zero to 200% of the initial performance units granted, to be determined upon completion of the three-year performance period. The number of units included as granted in the table above assumes the award will vest at 100% of the target units.

The weighted-average fair value for these cash-settled awards is based on our closing stock price as of December 31, 2012. The fair value is re-determined at the end of each reporting period for purposes of remeasuring compensation expense associated with these cash-settled awards.

Cash-Settled Restricted Stock Units

Nonvested restricted stock units as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (unit data in thousands):

	Number of Units			Weighted- Average Fair  Value
Nonvested at beginning of period		—
Granted		19
Vested		—
Cancelled/forfeited		(5	)
Nonvested at end of period		14		$	26.20

The weighted-average fair value for these cash-settled awards is based on our closing stock price as of December 31, 2012. The fair value is re-determined at the end of each reporting period for purposes of remeasuring compensation expense associated with these cash-settled awards.

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MII Stock Options

The following summarizes the assumptions used for stock options granted to our employees prior to the spin-off. The fair value of each option grant was estimated at the date of grant using Black-Scholes, with the following weighted-average assumptions:

	Year Ended December 31, 2010
Risk-free interest rate		2.18	%
Expected volatility		0.55
Expected life of the option in years		4.79
Expected dividend yield		0	%

The risk-free interest rate was based on the implied yield on a U.S. Treasury zero-coupon issue with a remaining term equal to the expected life of the option. The expected volatility was based on implied volatility from publicly traded options on MII’s common stock, historical volatility of the price of MII’s common stock and other factors. The expected life of the option was based on observed historical patterns. The expected dividend yield is based on the projected annual dividend payment per share divided by the stock price at the date of grant. This amount is zero because MII did not pay cash dividends in recent years.

Thrift Plan

On August 13, 2010, 5,000,000 of the authorized and unissued shares of B&W common stock were reserved for issuance for the employer match to the Thrift Plan. Those matching employer contributions equal 50% of the first 6% of compensation, as defined in the Thrift Plan, contributed by participants, and fully vest and are nonforfeitable after three years of service or upon retirement, death, lay-off or approved disability. The Thrift Plan allows employees to sell their interest in B&W’s common stock fund at any time, except as limited by applicable securities laws and regulations. During the year ended December 31, 2012, we issued 549,121 shares of B&W’s common stock as employer contributions pursuant to the Thrift Plan. At December 31, 2012, 3,721,670 shares of B&W’s common stock remained available for issuance under the Thrift Plan.

NOTE 10 – COMMITMENTS AND CONTINGENCIES

Investigations and Litigation

Nuclear Fuel Services, Inc.

In June 2011, approximately 18 plaintiffs filed a lawsuit styled as a “class action” in the U.S. District Court for the Eastern District of Tennessee against NFS, B&W, Babcock & Wilcox Power Generation Group, Inc. (“B&W PGG”), Babcock & Wilcox Technical Services Group, Inc. (“B&W TSG”), NOG-Erwin Holdings, Inc. and others relating to the operation of the NFS facility in Erwin, Tennessee. In October 2011, the plaintiffs filed a motion to amend the original complaint increasing the number of plaintiffs to approximately 140, and we filed a motion to dismiss. In December 2012, the court issued an order denying the plaintiffs’ motion to amend the original complaint and granting our motion to dismiss, with prejudice, all claims. The plaintiffs did not appeal and the judgment became final in January 2013. The plaintiffs sought compensatory and punitive damages alleging personal injuries and property damage resulting primarily from alleged releases of radioactive and other hazardous materials as a result of operations at the facility.

Apollo and Parks Township

In January 2010, Michelle McMunn, Cara D. Steele and Yvonne Sue Robinson filed suit against B&W PGG, B&W TSG, formerly known as B&W Nuclear Environmental Services, Inc. (the “B&W Parties”) and Atlantic Richfield Company (“ARCO”) in the United States District Court for the Western District of Pennsylvania. Since January 2010, additional suits have been filed by additional plaintiffs and there are currently eleven lawsuits pending in the U.S. District Court for the Western District of Pennsylvania against the B&W Parties and ARCO. Following the dismissal of a number of claims in June 2012, and the February 4, 2013 filing of an additional 10 primary

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claims, the suits presently involve approximately 85 primary claimants alleging, among other things, personal injuries and property damage as a result of alleged releases of radioactive material relating to the operation, remediation, and/or decommissioning of two former nuclear fuel processing facilities located in Apollo Borough and Parks Township, Pennsylvania (collectively, the “Apollo and Parks Litigation”). Those facilities previously were owned by Nuclear Materials and Equipment Company, a former subsidiary of ARCO (“NUMEC”), which was acquired by B&W PGG. The plaintiffs in the Apollo and Parks Litigation seek compensatory and punitive damages. Eleven of the suits have been consolidated for most non-dispositive pre-trial matters. No action has been taken on the most recent filing. Discovery in the Apollo and Parks Litigation is ongoing and no trial date has been set.

At the time of ARCO’s sale of NUMEC stock to B&W PGG, B&W PGG received an indemnity and hold harmless agreement from ARCO with respect to claims and liabilities arising prior to or as a result of conduct or events predating the acquisition.

Insurance coverage and/or the ARCO indemnity currently provides coverage for the claims alleged in the Apollo and Parks Litigation, although no assurance can be given that insurance and/or the indemnity will be available or sufficient in the event of liability, if any.

The B&W Parties and ARCO were defendants in a prior litigation filed in 1994 relating to the operation of the Apollo and Parks Township facilities in the matter of Donald F. Hall and Mary Ann Hall, et al., v. Babcock & Wilcox Company, et al. (the “Hall Litigation”). In 1998, the B&W Parties settled all then-pending and future punitive damage claims in the Hall Litigation for $8.0 million and sought reimbursement from third parties, including its insurers, American Nuclear Insurers and Mutual Atomic Energy Liability Underwriters (“ANI”). In 2008, ARCO settled the Hall Litigation with the plaintiffs for $27.5 million. The B&W Parties then settled the Hall Litigation in 2009 for $52.5 million, settling approximately 250 personal injury and wrongful death claims, as well as approximately 125 property damage claims, alleging damages as a result of alleged releases involving the facilities. ARCO and the B&W Parties retained their insurance rights against ANI in their respective settlements; however, under a related settlement regarding ARCO’s indemnification of B&W PGG relating to the two facilities, ARCO assigned to the B&W Parties 58.33% of the total of all ARCO’s proceeds/amounts recovered against ANI on account of the Hall Litigation.

The B&W Parties sought recovery from ANI for amounts paid by the B&W Parties to settle the Hall Litigation, along with unreimbursed attorneys fees, allocated amounts assigned by ARCO to the B&W Parties, and applicable interest based upon ANI’s breach of contract and bad faith conduct in the matter of The Babcock & Wilcox Company et al. v. American Nuclear Insurers, et al. (the “ANI Litigation”). ARCO also sought recovery against ANI in the ANI Litigation, which has been pending before the Court of Common Pleas of Allegheny County, Pennsylvania.

In September 2011, a jury returned a verdict in the ANI Litigation, finding that the B&W Parties’ settlement of the Hall Litigation for $52.5 million and ARCO’s settlement for $27.5 million were fair and reasonable. Following the verdict, in February 2012, the B&W Parties, ARCO and ANI entered into an agreement in which the parties agreed to the dismissal with prejudice of all remaining claims pending in the ANI Litigation, excluding the B&W Parties’ and ARCO’s claims seeking reimbursement from ANI for the $52.5 million and $27.5 million settlements (plus interest) (the “Settlement Claims”). By agreement, ANI also waived: (1) any and all rights to appeal the September 2011 jury verdict on the basis of the trial court’s evidentiary rulings; and (2) any defenses and arguments of any kind except ANI’s position that it was not required to reimburse the B&W Parties and ARCO for their settlements under the provisions of the ANI policies. In February 2012, the Court granted the parties’ proposed order implementing their agreement and entered final judgment in favor of the B&W Parties and ARCO on the Settlement Claims. As part of the final order and judgment, the Court ruled that the B&W Parties and ARCO are entitled to pre-judgment interest on their $52.5 million and $27.5 million settlements, in the amounts of approximately $8.8 million and $6.2 million, respectively. In addition, post-verdict interest from the date of the jury verdict was awarded at 6%. In March 2012, ANI filed a notice of appeal as to the final judgment and a supersedeas appeal bond in the amount of 120% of the total final judgment amount. The parties have filed their respective briefs with the Superior Court and oral arguments were held October 31, 2012. No ruling has yet been issued by the court.

Execution on the final judgment is stayed pending ANI’s appeal in the Pennsylvania appellate courts. Pursuant to the agreement among the parties, if the final judgment is affirmed, following the exhaustion of all appeals, ANI must immediately satisfy the judgment and pay an additional liquidated contingency sum of $5 million to the B&W

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Parties and ARCO. If on appeal the final judgment is reversed and/or vacated, ANI will not owe the liquidated contingency sum. B&W has not recognized any amounts claimed in the ANI Litigation in its financial statements due to the uncertainty surrounding the ultimate amount to be realized.

Other Litigation and Settlements

Additionally, due to the nature of our business, we are, from time to time, involved in routine litigation or subject to disputes or claims related to our business activities, including, among other things:

• performance- or warranty-related matters under our customer and supplier contracts and other business arrangements; and

• workers’ compensation claims, premises liability claims and other claims.

Based upon our prior experience, we do not expect that any of these other litigation proceedings, disputes and claims will have a material adverse effect on our consolidated financial condition, results of operations or cash flows.

Environmental Matters

We have been identified as a potentially responsible party at various cleanup sites under the Comprehensive Environmental Response, Compensation, and Liability Act, as amended (“CERCLA”). CERCLA and other environmental laws can impose liability for the entire cost of cleanup on any of the potentially responsible parties, regardless of fault or the lawfulness of the original conduct. Generally, however, where there are multiple responsible parties, a final allocation of costs is made based on the amount and type of wastes disposed of by each party and the number of financially viable parties, although this may not be the case with respect to any particular site. We have not been determined to be a major contributor of wastes to any of these sites. On the basis of our relative contribution of waste to each site, we expect our share of the ultimate liability for the various sites will not have a material adverse effect on our consolidated financial condition, results of operations or cash flows in any given year.

The Department of Environmental Protection of the Commonwealth of Pennsylvania (“PADEP”) advised us in March 1994 that it would seek monetary sanctions and remedial and monitoring relief related to the Parks Facilities. The relief sought is related to potential groundwater contamination resulting from previous operations at the facilities. These facilities are currently owned by a subsidiary in our Nuclear Operations segment. PADEP has advised us that it does not intend to assess any monetary sanctions, provided our Nuclear Operations segment continues its remediation program for the Parks Facilities. Whether additional nonradiation contamination remediation will be required at the Parks Facilities remains unclear. Results from sampling completed by our Nuclear Operations segment have indicated that such remediation may not be necessary. Our Nuclear Operations segment continues to evaluate closure of the groundwater issues pursuant to applicable Pennsylvania law.

We perform significant amounts of work for the U.S. Government under both prime contracts and subcontracts and operate certain facilities that are licensed to possess and process special nuclear materials. As a result of these activities, we are subject to continuing reviews by governmental agencies, including the U.S. Environmental Protection Agency and the NRC.

The NRC’s decommissioning regulations require our Nuclear Operations and Technical Services segments to provide financial assurance that it will be able to pay the expected cost of decommissioning each of its licensed facilities at the end of its service life. We provided financial assurance aggregating $43.5 million during the year ended December 31, 2012 with existing letters of credit for the ultimate decommissioning of these licensed facilities. These two facilities have provisions in their government contracts pursuant to which substantially all of our decommissioning costs and financial assurance obligations are covered by the DOE, including the costs to complete the decommissioning projects underway at the facility in Erwin, Tennessee. These letters of credit are to cover decommissioning required pursuant to work not subject to this DOE obligation.

Our compliance with U.S. federal, state and local environmental control and protection regulations resulted in pretax charges of approximately $15.3 million in the year ended December 31, 2012. In addition, compliance with existing environmental regulations necessitated capital expenditures of $3.2 million in the year ended December 31, 2012. At December 31, 2012 and 2011, we had total environmental reserves (including provisions for the facilities discussed above) of $49.6 million and $47.3 million, respectively. Of our total environmental reserves at December 31, 2012 and 2011, $3.1 million and $3.2 million, respectively, were included in current liabilities. In the year ended December 31, 2010 we recognized an $8.7 million gain, included in cost of operations in our consolidated and

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combined statements of income, attributable to a change in estimate of an environmental liability at our NFS subsidiary. Inherent in the estimates of those reserves and recoveries are our expectations regarding the levels of contamination, decommissioning costs and recoverability from other parties, which may vary significantly as decommissioning activities progress. Accordingly, changes in estimates could result in material adjustments to our operating results, and the ultimate loss may differ materially from the amounts that we have provided for in our consolidated financial statements.

Operating Leases

Future minimum payments required under operating leases that have initial or remaining noncancellable lease terms in excess of one year at December 31, 2012 are as follows (in thousands):

Fiscal Year Ending December 31,	Amount
2013	$	10,314
2014	$	9,168
2015	$	10,751
2016	$	4,761
2017	$	4,207
Thereafter	$	4,734

Total rental expense for the years ended December 31, 2012, 2011 and 2010 was $12.1 million, $11.1 million and $10.5 million, respectively. These expense amounts include contingent rentals and are net of sublease income, neither of which is material.

NOTE 11 – RELATED PARTY TRANSACTIONS

Prior to the spin-off, we were party to transactions with MII and its subsidiaries occurring in the normal course of operations.

Certain corporate and general and administrative expenses have been allocated to MII and its subsidiaries based on a level of effort calculation. We allocated expense of $20.0 million in the seven months ended July 31, 2010, which represented the period prior to our spin-off date.

We included in interest expense $8.7 million in the nine months ended September 30, 2010 attributable to an intercompany loan with a subsidiary of MII.

In connection with the accounting change described in Note 1, we adjusted our equity and related transactions prior to the spin-off. We recorded a cumulative reduction in parent equity as of January 1, 2010 of $554.8 million. Additionally, the related party transactions discussed below impacted our equity.

Dividend – In June 2010, we paid a dividend of $100.0 million to MII to maintain appropriate working capital needs. This amount was based on a determination by the MII Board of Directors after a review of the MII consolidated cash position and the respective foreseeable working capital and liquidity requirements for each of MII and B&W following the spin-off.

Net Transactions with Parent – In connection with the spin-off, capital in excess of par value increased by $523.6 million. This increase consisted primarily of the forgiveness of intercompany balances owed to MII of $178.0 million, the noncash settlement of a note payable to an MII affiliate totaling $277.8 million and the distribution by B&W of certain net assets totaling $20.7 million to MII, including $43.3 million in cash. In addition to these transactions, MII paid B&W $43.3 million in cash to settle a note receivable, and B&W paid MII $43.4 million in settlement of certain intercompany amounts. In addition, MII contributed net assets to B&W which included $12.5 million in cash.

See Note 3 for additional transactions with unconsolidated affiliates.

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NOTE 12 – RISKS AND UNCERTAINTIES

Percentage-of-Completion Accounting

As of December 31, 2012, in accordance with the percentage-of-completion method of accounting, we have provided for our estimated costs to complete all of our ongoing contracts. However, it is possible that current estimates could change due to unforeseen events, which could result in adjustments to overall contract costs. The risk on fixed-priced contracts is that revenue from the customer does not cover increases in our costs. It is possible that current estimates could materially change for various reasons, including, but not limited to, fluctuations in forecasted labor productivity or steel and other raw material prices. Increases in costs on our fixed-price contracts could have a material adverse impact on our consolidated financial condition, results of operations and cash flows. Alternatively, reductions in overall contract costs at completion could materially improve our consolidated financial condition, results of operations and cash flows.

Insurance

Upon the February 22, 2006 effectiveness of the settlement relating to the Chapter 11 proceedings involving several of our subsidiaries, most of our subsidiaries contributed substantial insurance rights to the asbestos personal injury trust, including rights to (1) certain pre-1979 primary and excess insurance coverages and (2) certain of our 1979-1986 excess insurance coverage. These insurance rights provided coverage for, among other things, asbestos and other personal injury claims, subject to the terms and conditions of the policies. The contribution of these insurance rights was made in exchange for the agreement on the part of the representatives of the asbestos claimants, including the representative of future claimants, to the entry of a permanent injunction, pursuant to Section 524(g) of the U.S. Bankruptcy Code, to channel to the asbestos trust all asbestos-related claims against our subsidiaries and former subsidiaries arising out of, resulting from or attributable to their operations, and the implementation of related releases and indemnification provisions protecting those subsidiaries and their affiliates from future liability for such claims. Although we are not aware of any significant, unresolved claims against our subsidiaries and former subsidiaries that are not subject to the channeling injunction and that relate to the periods during which such excess insurance coverage related, with the contribution of these insurance rights to the asbestos personal injury trust, it is possible that we could have underinsured or uninsured exposure for non-derivative asbestos claims or other personal injury or other claims that would have been insured under these coverages had the insurance rights not been contributed to the asbestos personal injury trust.

NOTE 13 – FINANCIAL INSTRUMENTS WITH CONCENTRATIONS OF CREDIT RISK

Our Power Generation and Nuclear Energy segments’ major customers are large utilities. The primary customer of our Nuclear Operations segment is the U.S. Government, including some of its contractors. These concentrations of customers may impact our overall exposure to credit risk, either positively or negatively, in that our customers may be similarly affected by changes in economic or other conditions. In the years ended December 31, 2012 and 2011, the U.S. Government accounted for approximately 34% and 38%, respectively, of our total revenues. See Note 17 for additional information about our operations in different geographic areas.

We believe that our provision for possible losses on uncollectible accounts receivable is adequate for our credit loss exposure. At December 31, 2012 and 2011, the allowance for possible losses that we deducted from accounts receivable – trade on the accompanying consolidated balance sheets was $3.8 million and $3.3 million, respectively.

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NOTE 14 – INVESTMENTS

The following is a summary of our available-for-sale securities at December 31, 2012:

	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Estimated Fair  Value
	(In thousands)
U.S. Government and agency securities	$	21,436	$	10	$	—		$	21,446
Mutual funds		2,958		679		—			3,637
Asset-backed securities and collateralized mortgage obligations		554		2		(102	)		454
Commercial paper		67,313		9		—			67,322
Total	$	92,261	$	700	$	(102	)	$	92,859

The following is a summary of our available-for-sale securities at December 31, 2011:

	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Estimated Fair  Value
	(In thousands)
U.S. Government and agency securities	$	51,308	$	14	$	—		$	51,322
Mutual funds		2,957		355		—			3,312
Asset-backed securities and collateralized mortgage obligations		633		—		(171	)		462
Commercial paper		17,481		4		(1	)		17,484
Total	$	72,379	$	373	$	(172	)	$	72,580

Proceeds, gross realized gains and gross realized losses on sales of available-for-sale securities were as follows:

	Proceeds		Gross Realized  Gains		Gross Realized  Losses
	(In thousands)
Year Ended December 31, 2012	$	247,649	$	35	$	—
Year Ended December 31, 2011	$	147,288	$	—	$	5
Year Ended December 31, 2010	$	134,276	$	—	$	122

NOTE 15 – DERIVATIVE FINANCIAL INSTRUMENTS

Our global operations give rise to exposure to market risks from changes in foreign currency exchange rates. We use derivative financial instruments, primarily foreign currency exchange (“FX”) forward contracts, to reduce the impact of changes in FX rates on our operating results. We use these instruments primarily to hedge our exposure associated with revenues or costs on our long-term contracts that are denominated in currencies other than our operating entities’ functional currencies. We do not hold or issue financial instruments for trading or other speculative purposes.

We enter into derivative financial instruments primarily as hedges of certain firm purchase and sale commitments denominated in foreign currencies. We record these contracts at fair value on our consolidated balance sheets. Depending on the hedge designation at the inception of the contract, the related gains and losses on these contracts are either deferred in stockholders’ equity as a component of accumulated other comprehensive income, until the hedged item is recognized in earnings, or offset against the change in fair value of the hedged firm commitment through earnings. Any ineffective portion of a derivative’s change in fair value and any portion excluded from the assessment of effectiveness are immediately recognized in other income (expense) – net in our consolidated and combined statements of income. The gain or loss on a derivative instrument not designated as a hedging instrument is also immediately recognized in earnings. Gains and losses on derivative financial instruments that require immediate recognition are included as a component of other income (expense) – net in our consolidated and combined statements of income.

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We have designated all of our FX forward contracts that qualify for hedge accounting as cash flow hedges. The hedged risk is the risk of changes in functional-currency-equivalent cash flows attributable to changes in spot exchange rates of forecasted transactions related to long-term contracts. We exclude from our assessment of effectiveness the portion of the fair value of the forward contracts attributable to the difference between spot exchange rates and forward exchange rates. At December 31, 2012, we had deferred approximately $2.1 million of net gains on these derivative financial instruments in accumulated other comprehensive income. We expect to recognize this entire amount in the next twelve months.

At December 31, 2012, all of our derivative financial instruments consisted of FX forward contracts and warrants to purchase common stock. The notional amount of our FX forward contracts totaled $170.3 million at December 31, 2012, with maturities extending to July 2014. These instruments consist primarily of contracts to purchase or sell Canadian Dollars or Danish Kroner. The fair value of these contracts totaled $3.3 million, all of which are Level 2 in nature (See Note 16). The fair value of our warrants, which are related to our investment in USEC Inc. described in Note 2, totaled $0.3 million at December 31, 2012, and is Level 3 in nature. We are exposed to credit-related losses in the event of nonperformance by counterparties to derivative financial instruments. We attempt to mitigate this risk by using major financial institutions with high credit ratings. The counterparties to all of our FX forward contracts are financial institutions included in our credit facility. Our hedge counterparties have the benefit of the same collateral arrangements and covenants as described under this facility.

The following tables summarize our derivative financial instruments at December 31, 2012 and 2011:

	Asset and Liability Derivatives
	December 31,
	2012		2011
	(In thousands)
Derivatives Designated as Hedges:
Foreign Exchange Contracts:
Location
Accounts receivable-other	$	2,251	$	1,760
Other assets	$	3,777	$	3,792
Accounts payable	$	1,893	$	1,238
Other liabilities	$	29	$	610
Derivatives Not Designated as Hedges:
Foreign Exchange Contracts:
Location
Other assets	$	191	$	—
Accounts payable	$	962	$	520
Other liabilities	$	—	$	664
Stock Warrants:
Location
Other assets	$	317	$	877

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The effects of derivatives on our financial statements are outlined below:

	December 31,
	2012			2011
	(In thousands)
Derivatives Designated as Hedges:
Cash Flow Hedges:
Foreign Exchange Contracts:
Amount of gain (loss) recognized in other comprehensive income	$	2,031		$	(1,224	)
Income (loss) reclassified from accumulated other comprehensive loss into income: effective portion
Location
Revenues	$	(1,082	)	$	4,128
Cost of operations	$	3,833		$	(2,350	)
Other-net	$	(24	)	$	373
Gain (loss) recognized in income: portion excluded from effectiveness testing
Location
Other-net	$	(185	)	$	1,045
Derivatives Not Designated as Hedges:
Forward Contracts:
Gain (loss) recognized in income
Location
Other-net	$	(169	)	$	1,234
Stock Warrants:
Loss recognized
Location
Other-net	$	(560	)	$	(2,419	)

NOTE 16 – FAIR VALUES OF FINANCIAL INSTRUMENTS

FASB Topic Fair Value Measurements and Disclosures defines fair value as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. This topic also sets forth the disclosure requirements regarding fair value and establishes a hierarchy for valuation inputs that emphasizes the use of observable inputs when measuring fair value. A financial instrument’s categorization within the fair value hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The fair value hierarchy established by this topic is as follows:

• Level 1 – inputs are based upon quoted prices for identical instruments traded in active markets.

• Level 2 – inputs are based upon quoted prices for similar instruments in active markets, quoted prices for similar or identical instruments in inactive markets and model-based valuation techniques for which all significant assumptions are observable in the market or can be corroborated by observable market data for substantially the full term of the assets and liabilities.

• Level 3 – inputs are generally unobservable and typically reflect management’s estimates of assumptions that market participants would use in pricing the asset or liability. The fair values are therefore determined using model-based techniques that include option pricing models, discounted cash flow models and similar valuation techniques.

The following sections describe the valuation methodologies we use to measure the fair values of our available-for-sale securities, derivatives and nonrecurring fair value measurements.

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Available-for-Sale-Securities

Investments other than derivatives primarily include U.S. Government and agency securities, money-market funds, mortgage-backed securities and corporate notes and bonds.

In general, and where applicable, we principally use a composite of observable prices and quoted prices in active markets for identical assets or liabilities to determine fair value. This pricing methodology applies to our Level 1 and 2 investments.

Our net unrealized gain/loss on investments is currently in an unrealized gain position totaling approximately $0.6 million at December 31, 2012. At December 31, 2011, we had an unrealized gain on our investments totaling approximately $0.2 million. Based on our analysis of these investments, we believe that none of our available-for-sale securities were other than temporarily impaired at December 31, 2012.

Fair Value Measurements

The following is a summary of our available-for-sale securities measured at fair value at December 31, 2012:

	12/31/12		Level 1		Level 2		Level 3
	(In thousands)
Mutual funds	$	3,637	$	—	$	3,637	$	—
U.S. Government and agency securities		21,446		21,446		—		—
Asset-backed securities and collateralized mortgage obligations		454		—		454		—
Commercial paper		67,322		—		67,322		—
Total	$	92,859	$	21,446	$	71,413	$	—

The following is a summary of our available-for-sale securities measured at fair value at December 31, 2011:

	12/31/11		Level 1		Level 2		Level 3
	(In thousands)
Mutual funds	$	3,312	$	—	$	3,312	$	—
U.S. Government and agency securities		51,322		51,322		—		—
Asset-backed securities and collateralized mortgage obligations		462		—		462		—
Commercial paper		17,484		—		17,484		—
Total	$	72,580	$	51,322	$	21,258	$	—

Derivatives

Level 2 derivative assets and liabilities currently consist of FX rate derivatives. Where applicable, the value of these derivative assets and liabilities is computed by discounting the projected future cash flow amounts to present value using market-based observable inputs, including FX forward and spot rates, interest rates and counterparty performance risk adjustments. At December 31, 2012, we had forward contracts outstanding to purchase or sell foreign currencies, primarily Canadian Dollars and Danish Kroner with a total notional amount of $170.3 million and a total fair value of $3.3 million.

Level 3 derivative assets include warrants to purchase common stock. The value of the warrants are computed using an option pricing model based on unobservable inputs such as a 40% stock price discount for inactive shares, and observable inputs, including interest rates and volatility. At December 31, 2012, the warrants had a fair value of $0.3 million.

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Changes in Level 3 Instrument

The following is a summary of the changes in our Level 3 instrument measured on a recurring basis for the years ended December 31, 2012 and 2011:

	Year ended December 31,
	2012			2011
	(In thousands)
Balance at beginning of period	$	877		$	3,296
Total realized and unrealized gains (losses):
Included in other income (expense)-net		(560	)		(2,419	)
Included in other comprehensive income		—			—
Purchases, issuances, and settlements		—			—
Principal repayments		—			—
Balance at end of period	$	317		$	877

Nonrecurring Fair Value Measurements

As described in Note 2, we performed a fair value analysis of our USEC Preferred Stock investment in the third quarter of 2012 for impairment purposes resulting in a fair value determination of $19.1 million. Fair value was determined using a combination of an option pricing model and a probability of default methodology. The fair value has been classified as Level 3 of the fair value hierarchy. The fair value measurement includes unobservable inputs for estimated default recovery rates ranging from 30% to 50%.

Other Financial Instruments

We used the following methods and assumptions in estimating our fair value disclosures for our other financial instruments, as follows:

Cash and cash equivalents and restricted cash and cash equivalents. The carrying amounts that we have reported in the accompanying consolidated balance sheets for cash and cash equivalents approximate their fair values due to their highly liquid nature. The fair value has been classified as Level 1 of the fair value hierarchy.

Long- and short-term debt. We base the fair values of debt instruments on quoted market prices. Where quoted prices are not available, we base the fair values on the present value of future cash flows discounted at estimated borrowing rates for similar debt instruments or on estimated prices based on current yields for debt issues of similar quality and terms. The fair value of our debt instruments approximated their carrying value at December 31, 2012 and December 31, 2011. The fair value has been classified as Level 2 of the fair value hierarchy.

NOTE 17 – SEGMENT REPORTING

Our reportable segments are Power Generation, Nuclear Operations, Technical Services and Nuclear Energy, as described in Note 1. The operations of our segments are managed separately and each has unique technology, services and customer class.

We account for intersegment sales at prices that we generally establish by reference to similar transactions with unaffiliated customers. Reportable segments are measured based on operating income exclusive of general corporate expenses, contract and insurance claims provisions, legal expenses and gains (losses) on sales of corporate assets. As described in Note 1, we have changed our accounting method regarding recognition of actuarial gains and losses. We have excluded from reportable segments the fourth quarter recognition of actuarial gains and losses as described in Note 1. Accordingly, we have adjusted previously disclosed segment information for this change in accounting.

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1. Information about Operations in our Different Industry Segments:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
REVENUES (1):
Power Generation	$	1,785,959		$	1,541,509		$	1,424,574
Nuclear Operations		1,098,031			1,043,185			995,969
Technical Services		107,851			119,711			90,147
Nuclear Energy		325,953			321,406			196,282
Adjustments and Eliminations		(26,435	)		(73,771	)		(18,161	)
	$	3,291,359		$	2,952,040		$	2,688,811

⁽¹⁾  Segment revenues are net of the following intersegment transfers and other adjustments:

Power Generation Transfers	$	7,932	$	53,852	$	5,092
Nuclear Operations Transfers		6,015		5,860		4,423
Technical Services Transfers		3,496		2,155		2,438
Nuclear Energy Transfers		8,992		11,904		6,208
	$	26,435	$	73,771	$	18,161

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	Year Ended December 31,
	2012			2011			2010
	(In thousands)
OPERATING INCOME:
Power Generation	$	183,387		$	183,984		$	169,113
Nuclear Operations		226,269			194,438			168,636
Technical Services		59,655			69,915			47,122
Nuclear Energy		(62,879	)		(116,887	)		(26,442	)
	$	406,432		$	331,450		$	358,429
Unallocated Corporate(1)		(27,953	)		(20,361	)		(18,029	)
Mark to Market Adjustment		(31,890	)		(215,418	)		(91,545	)
Total Operating Income(2)	$	346,589		$	95,671		$	248,855
Other Income (Expense):
Interest income		1,491			1,342			1,187
Interest expense		(3,735	)		(4,543	)		(12,938	)
Other income (expense)—net		(24,927	)		2,028			(16,896	)
Total Other Expense		(27,171	)		(1,173	)		(28,647	)
Income before Provision for Income Taxes	$	319,418		$	94,498		$	220,208

⁽¹⁾       Unallocated corporate includes general corporate overhead not allocated to segments

⁽²⁾       Included in operating income is the following:

(Gains) Losses on Asset Disposals – Net:
Power Generation	$	3,276		$	(3,456	)	$	39
Nuclear Operations		(339	)		—			—
Technical Services		(1,517	)		—			61
Nuclear Energy		(1	)		96			(62	)
Unallocated Corporate		—			273			—
	$	1,419		$	(3,087	)	$	38
Equity in Income of Investees:
Power Generation	$	17,402		$	25,778		$	30,788
Nuclear Operations		—			—			—
Technical Services		49,621			52,877			43,294
Nuclear Energy		(314	)		—			—
	$	66,709		$	78,655		$	74,082

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	Year Ended December 31,
	2012		2011		2010
	(In thousands)
SEGMENT ASSETS:
Power Generation	$	1,059,824	$	1,325,959	$	1,082,801
Nuclear Operations		708,607		679,818		639,090
Technical Services		125,494		123,717		85,509
Nuclear Energy		401,233		347,158		339,457
Total Segment Assets		2,295,158		2,476,652		2,146,857
Corporate Assets		545,197		312,459		353,653
Total Assets	$	2,840,355	$	2,789,111	$	2,500,510
CAPITAL EXPENDITURES:
Power Generation	$	24,592	$	15,788	$	13,627
Nuclear Operations		44,810		32,082		24,718
Technical Services		—		—		15
Nuclear Energy		8,435		7,257		4,480
Segment Capital Expenditures		77,837		55,127		42,840
Corporate Capital Expenditures		8,798		8,747		20,809
Total Capital Expenditures	$	86,635	$	63,874	$	63,649
DEPRECIATION AND AMORTIZATION:
Power Generation	$	19,126	$	17,264	$	18,564
Nuclear Operations		32,013		38,169		36,955
Technical Services		244		262		263
Nuclear Energy		6,202		5,346		4,988
Segment Depreciation and Amortization		57,585		61,041		60,770
Corporate Depreciation and Amortization		12,112		11,962		10,863
Total Depreciation and Amortization	$	69,697	$	73,003	$	71,633
INVESTMENT IN UNCONSOLIDATED AFFILIATES:
Power Generation	$	139,399	$	124,686	$	95,527
Nuclear Operations		—		—		—
Technical Services		46,928		38,882		5,284
Nuclear Energy		27		—		—
Total Investment in Unconsolidated Affiliates	$	186,354	$	163,568	$	100,811

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2. Information about our Product and Service Lines:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
REVENUES:
Power Generation:
New Build Environmental Equipment	$	446,514		$	235,750		$	277,531
New Build Steam Generation Systems		511,201			416,779			386,356
Aftermarket Services		841,571			894,677			765,573
Eliminations/Other		(13,327	)		(5,697	)		(4,886	)
		1,785,959			1,541,509			1,424,574
Nuclear Operations:
Nuclear Component Program		1,086,081			1,025,838			986,952
Commercial Operations		5,908			11,674			4,449
Eliminations/Other		6,042			5,673			4,568
		1,098,031			1,043,185			995,969
Technical Services:
Commercial Operations		20,819			29,708			28,862
Nuclear Environmental Services		78,228			76,267			48,351
Management & Operation Contracts of U.S. Government Facilities		8,804			13,736			12,934
Eliminations/Other		—			—			—
		107,851			119,711			90,147
Nuclear Energy:
Nuclear Services		158,365			151,118			119,244
Nuclear Equipment		134,011			122,789			72,336
Nuclear Projects		33,319			45,539			4,700
Eliminations/Other		258			1,960			2
		325,953			321,406			196,282
Eliminations		(26,435	)		(73,771	)		(18,161	)
	$	3,291,359		$	2,952,040		$	2,688,811

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3. Information about our Operations in Different Geographic Areas:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
REVENUES(1):
United States	$	2,615,387	$	2,340,299	$	2,133,924
Canada		288,246		238,663		252,089
Sweden		101,688		94,337		48,632
China		45,830		48,153		48,285
Germany		34,364		8,222		3,464
Argentina		23,529		21,016		4,374
Denmark		18,504		12,310		15,040
Finland		17,143		20,723		4,040
Korea		14,461		6,272		9,114
India		13,306		8,891		16,277
Chile		11,582		6,811		2,870
Norway		9,939		29,844		33,353
Italy		8,477		6,516		11,361
Saudi Arabia		7,973		3,307		1,689
Indonesia		7,828		4,642		6,048
United Kingdom		6,653		6,150		6,791
Japan		6,497		8,716		8,797
Bulgaria		2,620		14,149		2,144
Brazil		2,585		4,671		2,957
France		2,384		3,433		5,373
Ireland		2,189		14,769		26,574
Other Countries		50,174		50,146		45,615
	$	3,291,359	$	2,952,040	$	2,688,811
(1)       We allocate geographic revenues based on the location of the customer’s operations.
NET PROPERTY, PLANT AND EQUIPMENT:
United States	$	363,447	$	348,498	$	345,848
Canada		45,402		41,868		41,959
United Kingdom		9,714		9,758		10,401
Denmark		8,565		8,813		8,395
Mexico		8,302		7,024		6,299
Other Countries		11,591		6,330		5,410
	$	447,021	$	422,291	$	418,312

4. Information about our Major Customers:

In the years ended December 31, 2012, 2011 and 2010, the U.S. Government accounted for approximately 34%, 38% and 39%, respectively, of our total revenues. Substantially, these revenues are included in our Nuclear Operations and Technical Services segments.

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NOTE 18 – QUARTERLY FINANCIAL DATA (UNAUDITED)

The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 2012 and 2011:

	Year Ended December 31, 2012 Quarter Ended
	March  31, 2012		June  30, 2012		Sept. 30, 2012		Dec. 31, 2012
	(In thousands, except per share amounts)
Revenues	$	765,892	$	852,585	$	807,586	$	865,296
Operating income (1)	$	86,420	$	110,077	$	84,399	$	65,693
Equity in income of investees	$	17,357	$	16,687	$	14,546	$	18,119
Net income attributable to The Babcock & Wilcox Company	$	59,950	$	77,231	$	51,443	$	39,071
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	0.51	$	0.65	$	0.43	$	0.33
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	0.50	$	0.65	$	0.43	$	0.33
(1)       Includes equity in income of investees.

	Year Ended December 31, 2011 Quarter Ended
	March  31, 2011		June  30, 2011		Sept. 30, 2011		Dec. 31, 2011
	(In thousands, except per share amounts)
Revenues	$	691,277	$	752,352	$	707,622	$	800,789
Operating income (loss) (1)	$	41,394	$	82,809	$	74,912	$	(103,444	)
Equity in income of investees	$	15,361	$	18,381	$	22,782	$	22,131
Net income (loss) attributable to The Babcock & Wilcox Company	$	25,921	$	58,665	$	56,742	$	(63,009	)
Earnings per common share:
Basic:
Net income (loss) attributable to The Babcock & Wilcox Company	$	0.22	$	0.50	$	0.48	$	(0.53	)
Diluted:
Net income (loss) attributable to The Babcock & Wilcox Company	$	0.22	$	0.50	$	0.48	$	(0.53	)
(1)       Includes equity in income of investees.

Our March 31, 2011 quarter included additional costs to complete projects totaling $32.7 million. Our June 30, 2011 quarter included $10.9 million of favorable settlements with the sellers of NFS. In addition, our June 30, 2011 and September 30, 2011 quarters included additional costs to complete projects totaling $26.0 million and $3.1 million respectively. Our June 30, 2012 quarter included an $18.1 million favorable settlement with Energy Northwest. Our September 30, 2012 quarter included a $27.0 million impairment of our investment in USEC, Inc. with no related tax benefit and a $25.3 million reduction in our provision for income taxes related to the recognition of previously unrecognized tax benefits.

112

We have retrospectively applied the new accounting method for recognizing actuarial gains and losses, as described in Note 1. The impact of these adjustments on previously reported quarterly results is summarized below (in thousands, except per share amounts):

Increase (Decrease) from	First Quarter				Second Quarter				Third Quarter				Fourth Quarter
Previously Reported Amounts	2012		2011		2012		2011		2012		2011		2012			2011
Operating income	$	20,709	$	19,493	$	20,718	$	19,552	$	17,092	$	17,361	$	(12,486	)	$	(196,703	)
Net income attributable to The Babcock & Wilcox Company	$	13,206	$	12,411	$	13,207	$	12,456	$	10,922	$	11,079	$	(8,692	)	$	(127,281	)
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	0.11	$	0.10	$	0.11	$	0.11	$	0.09	$	0.09	$	(0.07	)	$	(1.07	)
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	0.11	$	0.11	$	0.11	$	0.11	$	0.09	$	0.09	$	(0.07	)	$	(1.07	)

NOTE 19 – EARNINGS PER SHARE

The following table sets forth the computation of basic and diluted earnings per share:

	Year Ended December 31,
	2012		2011		2010
	(In thousands, except shares and per share amounts)
Basic:
Net income attributable to The Babcock & Wilcox Company	$	227,695	$	78,319	$	139,939
Weighted average common shares		118,418,930		117,560,594		116,260,425
Basic earnings per common share:
Net income attributable to The Babcock & Wilcox Company	$	1.92	$	0.67	$	1.20
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	227,695	$	78,319	$	139,939
Weighted average common shares (basic)		118,418,930		117,560,594		116,260,425
Effect of dilutive securities:
Stock options, restricted stock and performance shares(1)		602,394		844,003		1,365,640
Adjusted weighted average common shares		119,021,324		118,404,597		117,626,065
Diluted earnings per common share:
Net income attributable to The Babcock & Wilcox Company	$	1.91	$	0.66	$	1.19

(1) At December 31, 2012, 2011 and 2010, we excluded from the diluted share calculation 1,082,904, 742,035 and 349,744 shares, respectively, related to stock options, as their effect would have been antidilutive.

113

NOTE 20 – EFFECT OF ACCOUNTING CHANGE

We have retrospectively applied the new accounting method for recognizing actuarial gains and losses, as described in Note 1. We recorded a cumulative reduction to parent equity as of January 1, 2010 of $554.8 million related to this accounting method change. The impact of these adjustments on our consolidated and combined results and financial position is summarized below.

	2012						2011						2010
	New Method			Historical Method			As Adjusted			Previously Reported			As Adjusted			Previously Reported
	(In thousands, except per share amounts)
Consolidated and Combined Statements of Income:
Cost of operations	$	2,461,205		$	2,500,858		$	2,384,154		$	2,278,208		$	2,032,347		$	2,024,034
Selling, general and administrative expenses	$	428,293		$	434,673		$	447,561		$	413,210		$	412,486		$	405,682
Other income (expense)—net	$	(24,927	)	$	(24,903	)	$	2,028		$	2,168		$	(16,896	)	$	(16,400	)
Provision for income taxes	$	101,861		$	84,495		$	23,880		$	72,982		$	80,005		$	82,294
Net income	$	217,557		$	188,914		$	70,618		$	161,953		$	140,203		$	153,526
Net income attributable to The Babcock & Wilcox Company	$	227,695		$	199,052		$	78,319		$	169,654		$	139,939		$	153,262
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	1.92		$	1.68		$	0.67		$	1.44		$	1.20		$	1.32
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	1.91		$	1.67		$	0.66		$	1.43		$	1.19		$	1.30
Consolidated and Combined Statements of Comprehensive Income:
Unrecognized losses arising during the period	$	(434	)	$	(21,486	)	$	(1,205	)	$	(140,436	)	$	(551	)	$	(62,059	)
Amortization of losses included in net income	$	2,281		$	51,976		$	2,487		$	50,382		$	2,386		$	50,571
Consolidated Balances Sheets:
Capital in excess of par value	$	713,257		$	1,143,275		$	676,952		$	1,106,971
Retained earnings	$	349,063		$	455,855		$	130,890		$	266,325
Accumulated other comprehensive income (loss)	$	32,728		$	(504,082	)	$	26,826		$	(538,628	)
Consolidated and Combined Statements of Cash Flows:
Net income	$	217,557		$	188,914		$	70,618		$	161,953		$	140,203		$	153,526
Provision for (benefit from) deferred taxes	$	43,038		$	25,672		$	(19,200	)	$	29,902		$	31,168		$	33,457
Recognition of losses and prior service cost for pension and postretirement plans	$	35,480		$	78,050		$	219,508		$	79,070		$	95,547		$	79,935

Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None

114

Item 9A. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

As of the end of the period covered by this annual report, we carried out an evaluation, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as that term is defined in Rules 13a-15(e) and 15d-15(e) adopted by the SEC under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)). Our disclosure controls and procedures were developed through a process in which our management applied its judgment in assessing the costs and benefits of such controls and procedures, which, by their nature, can provide only reasonable assurance regarding the control objectives. You should note that the design of any system of disclosure controls and procedures is based in part upon various assumptions about the likelihood of future events, and we cannot assure you that any design will succeed in achieving its stated goals under all potential future conditions, regardless of how remote. Based on the evaluation referred to above, our Chief Executive Officer and the Chief Financial Officer concluded that the design and operation of our disclosure controls and procedures are effective as of December 31, 2012 to provide reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC and such information is accumulated and communicated to management, including its principal executives and principal financial officers or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.

Management’s Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting (as that term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934) and for our assessment of the effectiveness of internal control over financial reporting.

Our internal control over financial reporting includes policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of our consolidated financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures are being made only in accordance with authorizations of our management and Board of Directors; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the consolidated and combined financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Our management, including our Chief Executive Officer and Chief Financial Officer, has conducted an assessment of the effectiveness of our internal control over financial reporting as of December 31, 2012, based on the framework established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (the “COSO Framework”). This assessment included an evaluation of the design of our internal control over financial reporting and testing of the operational effectiveness of those controls. Based on our assessment under the criteria described above, management has concluded that our internal control over financial reporting was effective as of December 31, 2012. Deloitte & Touche LLP has audited our internal control over financial reporting as of December 31, 2012, and their report is included in Item 9A.

Changes in Internal Control Over Financial Reporting

There has been no change in our internal control over financial reporting during the quarter ended December 31, 2012 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

115

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Stockholders of The Babcock & Wilcox Company:

We have audited the internal control over financial reporting of The Babcock & Wilcox Company and subsidiaries (the “Company”) as of December 31, 2012, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or person performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2012, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated and combined financial statements as of and for the year ended December 31, 2012 of the Company and our report dated February 27, 2013 expressed an unqualified opinion on those financial statements and included explanatory paragraphs regarding a change in the Company’s method of recognizing actuarial gains and losses for pension and other postretirement benefit plans for the year ended December 31, 2012 and a change to the operation of The Babcock & Wilcox Company as a subsidiary of McDermott International, Inc. for a portion of 2010.

/S/ DELOITTE & TOUCHE LLP

Charlotte, North Carolina

February 27, 2013

Item 9B. OTHER INFORMATION

None

116

PART III

Item 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

The information required by this item with respect to directors and executive officers is incorporated by reference to the material appearing under the headings “Election of Directors,” “Named Executive Profiles,” and “Executive Officers” in the Proxy Statement for our 2013 Annual Meeting of Stockholders. The information required by this item with respect to compliance with section 16(a) of the Securities and Exchange Act of 1934, as amended, is incorporated by reference to the material appearing under the heading “Section 16(a) Beneficial Ownership Compliance” in the Proxy Statement for our 2013 Annual Meeting of Stockholders. The information required by this item with respect to the Audit Committee and Audit and Finance Committee financial experts is incorporated by reference to the material appearing in the “Director Independence” and “Audit and Finance Committee” sections under the heading “Corporate Governance – Board of Directors and Its Committees” in the Proxy Statement for our 2013 Annual Meeting of Stockholders.

We have adopted a Code of Business Conduct for our employees and directors, including, specifically, our chief executive officer, our chief financial officer, our chief accounting officer, and our other executive officers. Our code satisfies the requirements for a “code of ethics” within the meaning of SEC rules. A copy of the code is posted on our web site, www.babcock.com under “Investor Relations – Corporate Governance – Highlights.”

Item 11. EXECUTIVE COMPENSATION

The information required by this item is incorporated by reference to the material appearing under the headings “Compensation Discussion and Analysis,” “Compensation of Directors,” “Compensation of Executive Officers,” “Compensation Committee Interlocks and Insider Participation” and “Compensation Committee Report” in the Proxy Statement for our 2013 Annual Meeting of Stockholders.

Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

The information required by this item is incorporated by reference to (1) the Equity Compensation Plan Information table appearing in Item 5 – “Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities” in Part II of this report and (2) the material appearing under the headings “Security Ownership of Directors and Executive Officers” and “Security Ownership of Certain Beneficial Owners” in the Proxy Statement for our 2013 Annual Meeting of Stockholders.

Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

The information in Note 11 to our consolidated and combined financial statements included in this report is incorporated by reference. Additional information required by this item is incorporated by reference to the material appearing under the headings “Corporate Governance – Director Independence” and “Certain Relationships and Related Transactions” in the Proxy Statement for our 2013 Annual Meeting of Stockholders.

Item 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

The information required by this item is incorporated by reference to the material appearing under the heading “Ratification of Appointment of Independent Registered Public Accounting Firm for Year Ending December 31, 2013” in the Proxy Statement for our 2013 Annual Meeting of Stockholders.

117

PART IV

Item 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES

The following documents are filed as part of this Annual Report or incorporated by reference:

1. CONSOLIDATED FINANCIAL STATEMENTS

Report of Independent Registered Public Accounting Firm

Consolidated Balance Sheets as of December 31, 2012 and 2011

Consolidated and Combined Statements of Income for the Years Ended December 31, 2012, 2011 and 2010

Consolidated and Combined Statements of Comprehensive Income for the Years Ended December 31, 2012, 2011 and 2010

Consolidated and Combined Statements of Stockholders’ Equity for the Years Ended December 31, 2012, 2011 and 2010

Consolidated and Combined Statements of Cash Flows for the Years Ended December 31, 2012, 2011 and 2010

Notes to Consolidated and Combined Financial Statements for the Years Ended December 31, 2012, 2011 and 2010

2. CONSOLIDATED FINANCIAL STATEMENT SCHEDULES

All schedules for which provision is made of the applicable regulations of the SEC have been omitted because they are not required under the relevant instructions or because the required information is included in the financial statements or the related footnotes contained in this report.

3. EXHIBITS

Exhibit Number                 Description

2.1	Master Separation Agreement dated as of July 2, 2010 between McDermott International, Inc. and The Babcock & Wilcox Company (incorporated by reference to Exhibit 2.1 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File no. 1-34658)).
3.1	Restated Certificate of Incorporation of The Babcock & Wilcox Company (incorporated by reference to Exhibit 3.1 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File No. 1-34658)).
3.2	Amended and Restated Bylaws of The Babcock & Wilcox Company (incorporated by reference to Exhibit 3.2 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File No. 1-34658)).
4.1	Amended and Restated Credit Agreement, dated as of June 8, 2012, entered into by and among The Babcock & Wilcox Company, certain lenders and letter of credit issuers executing the signature pages thereto and Bank of America, N.A., as administrative agent (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated June 8, 2012 (File No. 1-34658)).
4.2	Amended and Restated Pledge and Security Agreement, dated as of June 8, 2012, entered into by and among The Babcock & Wilcox Company and certain of its subsidiaries in favor of Bank of America, N.A., as administrative agent (incorporated by reference to Exhibit 10.2 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated June 8, 2012 (File No. 1-34658)).
10.1	Tax Sharing Agreement dated as of June 7, 2010 between J. Ray Holdings, Inc. and Babcock & Wilcox Holdings, Inc. (incorporated by reference to Exhibit 10.2 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File No. 1-34658)).

118

10.2	Securities Purchase Agreement dated as of May 25, 2010, by and among USEC Inc., Toshiba Corporation and Babcock & Wilcox Investment Company (incorporated by reference to Exhibit 10.18 to The Babcock & Wilcox Company’s Registration Statement on Form 10 filed on June 4, 2010 (File No. 1-34658)).
10.3	Standstill Agreement, dated as of June 30, 2011, among Toshiba America Nuclear Energy Corporation, Babcock & Wilcox Investment Company and USEC Inc. (incorporated by reference to Exhibit 10.3 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q dated August 8, 2011 (File No. 1-34658)).
10.4	First Amendment to Standstill Agreement, dated as of August 15, 2011, among Toshiba America Nuclear Energy Corporation, Babcock & Wilcox Investment Company and USEC Inc. (incorporated by reference to Exhibit 10.2 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 (File No. 1-34658)).
10.5	Second Amendment to Standstill Agreement, dated as of September 30, 2011, among Toshiba America Nuclear Energy Corporation, Babcock & Wilcox Investment Company and USEC Inc. (incorporated by reference to Exhibit 10.3 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 (File No. 1-34658)).
10.6*	2010 Long-Term Incentive Plan of The Babcock & Wilcox Company, effective July 2, 2010 (incorporated by reference to Exhibit 10.8 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File No. 1-34658)).
10.7*	Amended and Restated 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company, dated as of February 22, 2011, (incorporated by reference to Appendix A to The Babcock & Wilcox Company’s Proxy Statement dated April 1, 2011 (File No. 1-34658)).
10.8*	The Babcock & Wilcox Executive Incentive Compensation Plan, as amended and restated as of February 22, 2011, (incorporated by reference to Appendix B to The Babcock & Wilcox Company’s Proxy Statement dated April 1, 2011 (File No. 1-34658)).
10.9*	Supplemental Executive Retirement Plan of The Babcock & Wilcox Company, as amended and restated December 8, 2010, (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated December 8, 2010 (File No. 1-34658)).
10.10*	The Babcock & Wilcox Company Defined Contribution Restoration Plan, effective January 1, 2012 (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 (File No. 1-34658)).
10.11*	Form of Change In Control Agreement between E. James Ferland and The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.2 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated March 31, 2012 (File No. 1-34658)).
10.12*	Form of Change In Control Agreement between Anthony S. Colatrella and The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated November 14, 2011 (File No. 1-34658)).

119

10.13*	Change in Control Agreement entered into among The Babcock & Wilcox Company, Babcock & Wilcox Investment Company and Brandon C. Bethards effective as of August 11, 2010 (incorporated by reference to Exhibit 10.9 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2010 (File No. 1-34658)).
10.14*	Form of Change in Control Agreement entered into among The Babcock & Wilcox Company, certain employer subsidiaries and executive officers (other than Mr. Ferland or Mr. Colatrella) effective as of August 11, 2010 (incorporated by reference to Exhibit 10.11 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2010 (File No. 1-34658)).
10.15*	Form of Change in Control Agreement entered into among The Babcock & Wilcox Company, certain employer subsidiaries and selected officers (other than executive officers) effective as of August 11, 2010 (incorporated by reference to Exhibit 10.12 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2010 (File No. 1-34658)).
10.16*	2013 Notice of Grant under Amended and Restated 2010 Long-Term Inventive Plan of The Babcock & Wilcox Company.
10.17*	Form of 2013 Stock Option Grant Agreement for Employees.
10.18*	Form of 2013 Restricted Stock Unit Grant Agreement for Employees.
10.19*	Form of 2013 Performance Restricted Stock Units Grant Agreement for Employees.
10.20*	2012 Notice of Grant under Amended and Restated 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.27 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.21*	Form of 2012 Stock Option Grant Agreement for Employees (incorporated by reference to Exhibit 10.28 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.22*	Form of 2012 Restricted Stock Unit Grant Agreement for Employees (incorporated by reference to Exhibit 10.29 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.23*	Form of 2012 Performance Share Grant Agreement for Employees (incorporated by reference to Exhibit 10.30 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.24*	2011 Notice of Grant under Amended and Restated 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.23 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.25*	Form of 2011 Stock Option Grant Agreement for Employees (incorporated by reference to Exhibit 10.24 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).

120

10.26*	Form of 2011 Restricted Stock Unit Grant Agreement for Employees (incorporated by reference to Exhibit 10.25 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.27*	Form of 2011 Performance Share Grant Agreement for Employees (incorporated by reference to Exhibit 10.26 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.28*	Form of Restricted Stock Award Grant Agreement for Messrs. Bethards and Taff granted pursuant to the Restructuring Transaction Retention Agreements (incorporated by reference to Exhibit 10.27 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.29*	Form of 2010 Stock Option Grant Agreement for Employees (incorporated by reference to Exhibit 10.28 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.30*	Form of 2010 Restricted Stock Award Grant Agreement for Employees (incorporated by reference to Exhibit 10.29 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.31*	Form of 2010 Stock Option Grant Agreement for Employees converted on the spin-off from awards of stock options to purchase shares of McDermott International, Inc. common stock (incorporated by reference to Exhibit 10.30 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.32*	Form of 2010 Restricted Stock Award Grant Agreement for Employees converted on the spin-off from awards of restricted shares of McDermott International, Inc. common stock (incorporated by reference to Exhibit 10.31 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.33*	Form of 2010 Restricted Stock Unit Grant Agreement for Employees converted on the spin-off from awards of restricted stock units denominated in shares of McDermott International, Inc. common stock. (incorporated by reference to Exhibit 10.32 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.34*	Form of 2010 Restricted Stock Unit Grant Agreement for Employees converted on the spin-off from awards of performance shares denominated in shares of McDermott International, Inc. common stock (incorporated by reference to Exhibit 10.33 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.35*	Consulting Agreement, dated as of June 29, 2011, between The Babcock & Wilcox Company and Michael S. Taff (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated June 29, 2011 (File No. 1-34658)).
10.36*	Separation and Consulting Agreement between Brandon C. Bethards and The Babcock & Wilcox Company, dated April 5, 2012 (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated March 31, 2012 (File No. 1-34658)).

121

10.37*	Consulting Agreement by and between Babcock & Wilcox Power Generation Group, Inc. and Richard L. Killion dated as of July 9, 2012 (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated July 9, 2012 (File No. 1-34658)).
10.38*	The Babcock & Wilcox Company Executive Severance Plan dated November 5, 2012 (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated November 5, 2012 (File No. 1-34658)).
18	Letter on Change in Accounting Principles
21.1	Significant Subsidiaries of the Registrant.
23.1	Consent of Deloitte & Touche LLP.
31.1	Rule 13a-14(a)/15d-14(a) certification of Chief Executive Officer.
31.2	Rule 13a-14(a)/15d-14(a) certification of Chief Financial Officer.
32.1	Section 1350 certification of Chief Executive Officer.
32.2	Section 1350 certification of Chief Financial Officer.
95	Mine Safety
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
101.LAB	XBRL Taxonomy Extension Label Linkbase Document
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document

* Management contract or compensatory plan or arrangement.

122

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	THE BABCOCK & WILCOX COMPANY
February 27, 2013	By:	/s/ E. James Ferland
		E. James Ferland
		President and Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated and on the date indicated.

Signature	Title
/s/ E. James Ferland E. James Ferland	President and Chief Executive Officer (Principal Executive Officer)
/s/ Anthony S. Colatrella Anthony S. Colatrella	Senior Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Representative)
/s/ David S. Black David S. Black	Vice President and Chief Accounting Officer (Principal Accounting Officer and Duly Authorized Representative)
/s/ John A. Fees John A. Fees	Chairman of the Board and Director
/s/ Thomas A. Christopher Thomas A. Christopher	Director
/s/ Robert W. Goldman Robert W. Goldman	Director
/s/ Stephen G. Hanks Stephen G. Hanks	Director
/s/ D. Bradley McWilliams D. Bradley McWilliams	Director
/s/ Richard W. Mies Richard W. Mies	Director
/s/ Anne R. Pramaggiore Anne R. Pramaggiore	Director
/s/ Larry L. Weyers Larry L. Weyers	Director

February 27, 2013

123

INDEX TO EXHIBITS

Exhibit Number	Description	Sequentially Numbered Pages
2.1	Master Separation Agreement dated as of July 2, 2010 between McDermott International, Inc. and The Babcock & Wilcox Company (incorporated by reference to Exhibit 2.1 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File no. 1-34658)).
3.1	Restated Certificate of Incorporation of The Babcock & Wilcox Company (incorporated by reference to Exhibit 3.1 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File No. 1-34658)).
3.2	Amended and Restated Bylaws of The Babcock & Wilcox Company (incorporated by reference to Exhibit 3.2 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File No. 1-34658)).
4.1	Amended and Restated Credit Agreement, dated as of June 8, 2012, entered into by and among The Babcock & Wilcox Company, certain lenders and letter of credit issuers executing the signature pages thereto and Bank of America, N.A., as administrative agent (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated June 8, 2012 (File No. 1-34658)).
4.2	Amended and Restated Pledge and Security Agreement, dated as of June 8, 2012, entered into by and among The Babcock & Wilcox Company and certain of its subsidiaries in favor of Bank of America, N.A., as administrative agent (incorporated by reference to Exhibit 10.2 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated June 8, 2012 (File No. 1-34658)).
10.1	Tax Sharing Agreement dated as of June 7, 2010 between J. Ray Holdings, Inc. and Babcock & Wilcox Holdings, Inc. (incorporated by reference to Exhibit 10.2 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File No. 1-34658)).
10.2	Securities Purchase Agreement dated as of May 25, 2010, by and among USEC Inc., Toshiba Corporation and Babcock & Wilcox Investment Company (incorporated by reference to Exhibit 10.18 to The Babcock & Wilcox Company’s Registration Statement on Form 10 filed on June 4, 2010 (File No. 1-34658)).
10.3	Standstill Agreement, dated as of June 30, 2011, among Toshiba America Nuclear Energy Corporation, Babcock & Wilcox Investment Company and USEC Inc. (incorporated by reference to Exhibit 10.3 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q dated August 8, 2011 (File No. 1-34658)).
10.4	First Amendment to Standstill Agreement, dated as of August 15, 2011, among Toshiba America Nuclear Energy Corporation, Babcock & Wilcox Investment Company and USEC Inc. (incorporated by reference to Exhibit 10.2 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 (File No. 1-34658)).
10.5	Second Amendment to Standstill Agreement, dated as of September 30, 2011, among Toshiba America Nuclear Energy Corporation, Babcock & Wilcox Investment Company and USEC Inc. (incorporated by reference to Exhibit 10.3 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 (File No. 1-34658)).

10.6*	2010 Long-Term Incentive Plan of The Babcock & Wilcox Company, effective July 2, 2010 (incorporated by reference to Exhibit 10.8 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2010 (File No. 1-34658)).
10.7*	Amended and Restated 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company, dated as of February 22, 2011, (incorporated by reference to Appendix A to The Babcock & Wilcox Company’s Proxy Statement dated April 1, 2011 (File No. 1-34658)).
10.8*	The Babcock & Wilcox Executive Incentive Compensation Plan, as amended and restated as of February 22, 2011, (incorporated by reference to Appendix B to The Babcock & Wilcox Company’s Proxy Statement dated April 1, 2011 (File No. 1-34658)).
10.9*	Supplemental Executive Retirement Plan of The Babcock & Wilcox Company, as amended and restated December 8, 2010, (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated December 8, 2010 (File No. 1-34658)).
10.10*	The Babcock & Wilcox Company Defined Contribution Restoration Plan, effective January 1, 2012 (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2011 (File No. 1-34658)).
10.11*	Form of Change In Control Agreement between E. James Ferland and The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.2 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated March 31, 2012 (File No. 1-34658)).
10.12*	Form of Change In Control Agreement between Anthony S. Colatrella and The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated November 14, 2011 (File No. 1-34658)).
10.13*	Change in Control Agreement entered into among The Babcock & Wilcox Company, Babcock & Wilcox Investment Company and Brandon C. Bethards effective as of August 11, 2010 (incorporated by reference to Exhibit 10.9 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2010 (File No. 1-34658)).
10.14*	Form of Change in Control Agreement entered into among The Babcock & Wilcox Company, certain employer subsidiaries and executive officers (other than Mr. Ferland or Mr. Colatrella) effective as of August 11, 2010 (incorporated by reference to Exhibit 10.11 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2010 (File No. 1-34658)).
10.15*	Form of Change in Control Agreement entered into among The Babcock & Wilcox Company, certain employer subsidiaries and selected officers (other than executive officers) effective as of August 11, 2010 (incorporated by reference to Exhibit 10.12 to The Babcock & Wilcox Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2010 (File No. 1-34658)).
10.16*	2013 Notice of Grant under Amended and Restated 2010 Long-Term Inventive Plan of The Babcock & Wilcox Company.
10.17*	Form of 2013 Stock Option Grant Agreement for Employees.
10.18*	Form of 2013 Restricted Stock Unit Grant Agreement for Employees.
10.19*	Form of 2013 Performance Restricted Stock Units Grant Agreement for Employees.
10.20*	2012 Notice of Grant under Amended and Restated 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.27 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).

10.21*	Form of 2012 Stock Option Grant Agreement for Employees (incorporated by reference to Exhibit 10.28 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.22*	Form of 2012 Restricted Stock Unit Grant Agreement for Employees (incorporated by reference to Exhibit 10.29 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.23*	Form of 2012 Performance Share Grant Agreement for Employees (incorporated by reference to Exhibit 10.30 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.24*	2011 Notice of Grant under Amended and Restated 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (incorporated by reference to Exhibit 10.23 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2011 (File No. 1-34658)).
10.25*	Form of 2011 Stock Option Grant Agreement for Employees (incorporated by reference to Exhibit 10.24 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.26*	Form of 2011 Restricted Stock Unit Grant Agreement for Employees (incorporated by reference to Exhibit 10.25 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.27*	Form of 2011 Performance Share Grant Agreement for Employees (incorporated by reference to Exhibit 10.26 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.28*	Form of Restricted Stock Award Grant Agreement for Messrs. Bethards and Taff granted pursuant to the Restructuring Transaction Retention Agreements (incorporated by reference to Exhibit 10.27 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.29*	Form of 2010 Stock Option Grant Agreement for Employees (incorporated by reference to Exhibit 10.28 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.30*	Form of 2010 Restricted Stock Award Grant Agreement for Employees (incorporated by reference to Exhibit 10.29 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.31*	Form of 2010 Stock Option Grant Agreement for Employees converted on the spin-off from awards of stock options to purchase shares of McDermott International, Inc. common stock (incorporated by reference to Exhibit 10.30 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.32*	Form of 2010 Restricted Stock Award Grant Agreement for Employees converted on the spin-off from awards of restricted shares of McDermott International, Inc. common stock (incorporated by reference to Exhibit 10.31 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.33*	Form of 2010 Restricted Stock Unit Grant Agreement for Employees converted on the spin-off from awards of restricted stock units denominated in shares of McDermott International, Inc. common stock. (incorporated by reference to Exhibit 10.32 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).

10.34*	Form of 2010 Restricted Stock Unit Grant Agreement for Employees converted on the spin-off from awards of performance shares denominated in shares of McDermott International, Inc. common stock (incorporated by reference to Exhibit 10.33 to The Babcock & Wilcox Company’s Annual Report on Form 10-K for the year ended December 31, 2010 (File No. 1-34658)).
10.35*	Consulting Agreement, dated as of June 29, 2011, between The Babcock & Wilcox Company and Michael S. Taff (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated June 29, 2011 (File No. 1-34658)).
10.36*	Separation and Consulting Agreement between Brandon C. Bethards and The Babcock & Wilcox Company, dated April 5, 2012 (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated March 31, 2012 (File No. 1-34658)).
10.37*	Consulting Agreement by and between Babcock & Wilcox Power Generation Group, Inc. and Richard L. Killion dated as of July 9, 2012 (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated July 9, 2012 (File No. 1-34658)).
10.38*	The Babcock & Wilcox Company Executive Severance Plan dated November 5, 2012 (incorporated by reference to Exhibit 10.1 to The Babcock & Wilcox Company’s Current Report on Form 8-K dated November 5, 2012 (File No. 1-34658)).
18	Letter on Change in Accounting Principles
21.1	Significant Subsidiaries of the Registrant.
23.1	Consent of Deloitte & Touche LLP.
31.1	Rule 13a-14(a)/15d-14(a) certification of Chief Executive Officer.
31.2	Rule 13a-14(a)/15d-14(a) certification of Chief Financial Officer.
32.1	Section 1350 certification of Chief Executive Officer.
32.2	Section 1350 certification of Chief Financial Officer.
95	Mine Safety
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
101.LAB	XBRL Taxonomy Extension Label Linkbase Document
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document

* Management contract or compensatory plan or arrangement.

EX-10.16

Exhibit 10.16

Notice of Grant

Babcock & Wilcox Long-Term Incentives

[Date]

TO: [Name]

The Company is pleased to advise that you have been granted long-term incentives as follows:

Date of Grant:
Performance Restricted Stock Units Granted:
Restricted Stock Units Granted:
Non Qualified Stock Options Granted:	@

By your signature below, you agree that these incentives are granted under and governed by the terms and conditions of the 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (as amended and restated to date, the “Plan”), and the 2013 B&W Restricted Stock Units, Stock Options and Performance Restricted Stock Units Agreements, which are attached to and made a part of this document. A copy of the Plan and the Prospectus relating to the stock issued under the Plan can be found at http://equityawardcenter.schwab.com under the “At a Glance/My Company Info” tab in your Schwab account. The Plan and Prospectus are incorporated by reference and made a part of this document. If you would like to receive a copy of either the Plan or Prospectus, please contact              at [telephone number] or [email].

Please acknowledge (1) your receipt and acceptance of this Notice of Grant and accompanying long-term incentives and (2) your agreement with the terms contained in the Grant Agreement governing such long-term incentives, by signing both this Notice and the enclosed copy hereof and returning one such signed copy to The Babcock & Wilcox Company at The Harris Building, 13024 Ballantyne Corporate Place, Charlotte, NC 28277, Attention: [Name], and marked “Personal and Confidential.” Your long-term incentives will not be effective until you return a signed copy of this Notice. Please do so no later than 30 days from the date of the Notice.

	Date:
[Name]

EX-10.17

Exhibit 10.17

2013 STOCK OPTION

GRANT AGREEMENT

Effective [insert date], 2013 (the “Date of Grant”), the Compensation Committee of the Board of Directors (the “Committee”) of The Babcock & Wilcox Company (“B&W”) selected you to receive a grant of Non-Qualified Stock Options (the “Options”) under the 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company, as amended and restated February 22, 2011 (the “Plan”). The provisions of the Plan are incorporated herein by reference.

Any reference or definition contained in this Agreement shall, except as otherwise specified, be construed in accordance with the terms and conditions of the Plan and all determinations and interpretations made by the Committee with regard to any question arising hereunder or under the Plan shall be binding and conclusive on you and your legal representatives and beneficiaries. The term “B&W” as used in this Agreement with reference to employment shall include subsidiaries of B&W (including unconsolidated joint ventures). Whenever the words “you or your” are used in any provision of this Agreement under circumstances where the provision should logically be construed to apply to the beneficiary, estate, or personal representative, to whom any rights under this Agreement may be transferred by will or by the laws of descent and distribution, it shall be deemed to include such person.

Subject to the provisions of the Plan, the terms and conditions of this grant are as follows:

1. Number and Price of Options – B&W grants to you the option to purchase from B&W at the price of [$____]/share up to, but not exceeding in the aggregate, the number of shares of B&W common stock as shown on the attached Notice of Grant (which is incorporated herein by reference) and as explained hereinafter and in the Plan.

2. Option Term – Options have been granted for a period of seven (7) years from the Date of Grant (the “Option Term”).

3. Vesting of Options – Subject to the “Forfeiture of Options” paragraph below, options do not provide you with any rights or interest therein until they vest and become exercisable in one-third (1/3) increments on the first, second and third anniversaries of the Date of Grant. Options which are or become exercisable at the time of termination of employment continue to be exercisable until terminated in accordance with Paragraph 6 below.

Prior to the third anniversary of the Date of Grant, all unvested Options shall become vested and exercisable on the earliest to occur of: (1) the date of termination of your employment from B&W due to death, (2) your disability (as defined in the Plan) or (3) the date a change in control (as defined in the Plan) occurs.

If your employment is terminated prior to the third anniversary of the Date of Grant due to Retirement, 25% of the then-unvested outstanding Options will become vested and exercisable provided your termination date is on or after the first anniversary of the Date of Grant but prior to the second anniversary, and 50% of the then-unvested outstanding Options will become vested and exercisable provided your termination date is on or after the second anniversary of the Date of Grant but prior to the third anniversary. For this purpose, “Retirement” means a voluntary termination of employment after attaining age 60 and completing 10 years of service with B&W, or an involuntary termination due to reduction in force. For purposes of this

Agreement, a reduction in force shall mean a termination of employment due to elimination of a previously required position or previously required services, or due to the consolidation of departments, abandonment of plants or offices, technological change or declining business activities, where such termination is intended to be permanent; or under other circumstances which the Committee, in accordance with standards uniformly applied with respect to all similarly situated employees, designates as a reduction in force.

The Committee may provide for additional vesting under other circumstances, in its sole discretion.

4. Forfeiture of Options—Options which are not or do not become vested and exercisable at your termination of employment with B&W for any reason shall, coincident therewith, terminate and be of no force and effect.

In the event that (i) you are convicted of (1) a felony or (2) misdemeanor involving fraud, dishonesty or moral turpitude, or (ii) you engage in conduct that adversely effects or may reasonably be expected to adversely affect the business reputation or economic interests of B&W, as determined in the sole discretion of the Committee, then all outstanding Options awarded to you under this grant terminate and have no force and effect immediately upon notice of such conviction or determination. In addition, your right to exercise Options may be suspended during any inquiry regarding any such acts pending a final determination by the Committee. The provisions of this section 4 are in addition to the clawback provisions in section 10 below.

5. How to Exercise – Charles Schwab & Co., Inc. (“Schwab”) currently administers B&W’s stock plans and you must exercise your Options with Schwab. You have two ways to exercise your Options through Schwab:

1. Online – [Insert website address]; or

2. Telephone – [Insert telephone number].

Certain restrictions apply if you are a Section 16 insider. The Committee may change Plan administrators or exercise procedures from time to time. You will be notified of such changes, as applicable.

6. Termination of Options – The Options shall terminate and be of no force or effect as follows:

(a) If you continue in the employ of B&W through the Option Term, the Options will remain exercisable, subject to the terms hereof and the Plan, until the expiration of the Option Term, at which time the Options shall terminate and have no force or effect;

(b) If your employment involuntarily terminates during the Option Term by reason of a Retirement or disability, the Options will remain exercisable, subject to the terms hereof and the Plan, until the expiration of the Option Term, at which time the Options shall terminate and have no force or effect;

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(c) If your employment terminates during the Option Term by reason of death, the Options terminate and have no force or effect three (3) years after the date of death, or upon the expiration of the Option Term, whichever occurs first;

(d) If your employment terminates during the Option Term for any other reason, the Options terminate and have no force or effect upon the expiration of twelve (12) months after your termination of employment or the expiration of the Option Term, whichever occurs first.

7. Who Can Exercise – During your lifetime the Options shall be exercisable only by you. No assignment or transfer of the Options, whether voluntary or involuntary, by operation of law or otherwise, except by will or the laws of descent and distribution or pursuant to a qualified domestic relations order, shall vest in the assignee or transferee any interest whatsoever.

8. Securities and Exchange Commission Requirements. If you are a Section 16 insider, this type of transaction must be reported on a Form 4 before the end of the second (2) business day following the Date of Grant. Please be aware that if you are going to reject the grant, you should do so immediately after the Date of Grant to avoid potential Section 16 liability. Please advise Kathy Peres or Angie Winter immediately by e-mail, fax or telephone call if you intend to reject this grant. Absent such notice of rejection, B&W will prepare and file the required Form 4 on your behalf within the required two business day deadline. If Section 16 applies to you, you are also subject to Rule 144. This Rule is applicable only when the shares are sold, so you need not take any action under Rule 144 at this time.

Those of you covered by these requirements have already been advised of your status. Others of you may become Section 16 insiders at some future date, in which case reporting will be required at that time.

9. Taxes. You will recognize income upon the exercise of Options in accordance with the tax laws of the jurisdiction that is applicable to you. State income tax and FICA withholding may also be required and will be withheld in the same manner. You agree to promptly pay to B&W the amount of income tax which B&W is required to withhold in connection with the income realized by you in connection with this grant and, unless prohibited by applicable law, that you hereby authorize B&W to withhold such amount, in whole or in part, from subsequent salary payments, without further notice to you. From time to time, the Committee may, in its sole discretion, determine to satisfy any statutory minimum withholding obligation by another method permitted by the Plan.

10. Clawback Provisions.

(a) Recovery of Options. In the event that B&W is required to prepare an accounting restatement due to the material noncompliance of B&W with any financial reporting requirement under the U.S. federal securities laws as a result of fraud (a “Restatement”) and the Board reasonably determines that you knowingly engaged in the fraud, B&W will have the right to recover the Options granted during the three-year period preceding the date on which the Board or B&W, as applicable, determines it is required to prepare the Restatement (the “Three-Year Period”), or vested in whole or in part during the Three-Year Period, to the extent of any excess of what would have been granted to or would have vested for you under the Restatement.

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(b) Recovery Process. In the event a Restatement is required, the Board, based upon a recommendation by the Committee, will (a) review the Options either granted or vested in whole or in part during the Three-Year Period and (b) in accordance with the provisions of this Agreement and the Plan, will take reasonable action to seek recovery of the amount of such Options in excess of what would have been granted to or would have vested for you under the Restatement (but in no event more than the total amount of such Options), as such excess amount is reasonably determined by the Board in its sole discretion, in compliance with Section 409A of the Code. There shall be no duplication of recovery under Article 19 of the Plan and any of 15 U.S.C. Section 7243 (Section 304 of The Sarbanes-Oxley Act of 2002) and Section 10D of the Exchange Act.

11. Other. Neither the action of B&W in establishing the Plan, nor any action taken by it, by the Committee or the Board of Directors under the Plan nor any provisions of this Agreement shall be construed as giving to you the right to be retained in the employ of B&W.

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EX-10.18

Exhibit 10.18

2013 RESTRICTED STOCK UNITS

GRANT AGREEMENT

Effective [insert date], 2013 (the “Date of Grant”), the Compensation Committee of the Board of Directors (the “Committee”) of The Babcock & Wilcox Company (“B&W”) awarded you a grant of restricted stock units (“RSUs”) under the 2010 Long-Term Incentive Plan of B&W, as amended and restated February 22, 2011 (the “Plan”). The provisions of the Plan are incorporated herein by reference.

Any reference or definition contained in this Agreement shall, except as otherwise specified, be construed in accordance with the terms and conditions of the Plan and all determinations and interpretations made by the Committee with regard to any question arising hereunder or under the Plan shall be binding and conclusive on you and your legal representatives and beneficiaries. The term “B&W” as used in this Agreement with reference to employment shall include subsidiaries of B&W (including unconsolidated joint ventures). Whenever the words “you or your” are used in any provision of this Agreement under circumstances where the provision should logically be construed to apply to the beneficiary, estate, or personal representative, to whom any rights under this Agreement may be transferred by will or by the laws of descent and distribution, it shall be deemed to include such person.

Restricted Stock Units

RSU Award. You have been awarded the number of RSUs shown on the attached Notice of Grant (which is incorporated herein by reference). Each RSU represents a right to receive one share of B&W common stock on the Vesting Date, as set forth in the “Vesting Requirements” paragraph below.

Vesting Requirements. Subject to the “Forfeiture of RSUs” provision below, RSUs do not provide you with any rights or interest therein until they become vested under one or more of the following circumstances (each such circumstance a “Vesting Date”):

• in one-third (1/3) increments on the first, second and third anniversaries of the Date of Grant provided you are still employed on the applicable anniversary;

• 25% of the then-remaining outstanding RSUs (a) on your being or becoming retirement eligible or (b) if you are not then retirement eligible, your employment is involuntarily terminated by reason of a reduction in force, on or after the first anniversary and prior to the second anniversary of the Date of Grant;

• 50% of the then-remaining outstanding RSUs (a) on your being or becoming retirement eligible or (b) if you are not then retirement eligible, if your employment is involuntarily terminated by reason of a reduction in force, on or after the second anniversary and prior to the third anniversary of the Date of Grant;

• 100% of the then-remaining outstanding RSUs on the earliest to occur prior to the third anniversary of the Date of Grant of: (a) the date of termination of your employment from B&W due to death, (b) your disability (as defined in the Plan) or (c) the date a change in control (as defined in the Plan) occurs; and

• the Committee may provide for additional vesting under other circumstances, in its sole discretion.

For purposes of this Agreement, (a) “retirement eligible” means at least 60 years of age with 10 or more years of service with B&W and (b) a “reduction in force” means a termination of employment due to elimination of a previously required position or previously required services, or due to the consolidation of departments, abandonment of plants or offices, technological change or declining business activities, where such termination is intended to be permanent; or under other circumstances which the Committee, in accordance with standards uniformly applied with respect to all similarly situated employees, designates as a reduction in force. For the sole purpose of calculating the number of RSUs that vest in one-third increments, any RSUs that vest as a result of your being “retirement eligible” will be treated as an acceleration of the RSUs that are otherwise scheduled to vest in connection with the next one-third increment.

Forfeiture of RSUs. RSUs which are not or do not become vested upon your termination of employment shall, coincident therewith, terminate and be of no force or effect.

In the event that (a) you are convicted of (i) a felony or (ii) a misdemeanor involving fraud, dishonesty or moral turpitude, or (b) you engage in conduct that adversely affects or may reasonably be expected to adversely affect the business reputation or economic interests of B&W, as determined in the sole judgment of the Committee, then all RSUs and all rights or benefits awarded to you under this grant of RSUs are forfeited, terminated and withdrawn immediately upon such conviction or notice of such determination. The Committee shall have the right to suspend any and all rights or benefits awarded to you hereunder pending its investigation and final determination with regard to such matters. The forfeiture provisions of this paragraph are in addition to the provisions under the heading “Clawback Provisions” below.

Settlement of RSUs. RSUs shall be settled in shares of B&W common stock, which shares shall be distributed as soon as administratively practicable after the Settlement Date, but in no event later than March 15 following the end of the calendar year in which the Settlement Date occurs. For purposes of this Agreement, “Settlement Date” means either: (a) the applicable Vesting Date or, in the event you made a permitted deferral election pursuant to the Plan with respect to this grant, (b) the date(s) of the applicable distribution event in accordance with such deferral election.

Dividend, Voting Rights and Other Rights. You shall have no rights of ownership in the shares of B&W common stock underlying the RSUs and shall have no right to vote such shares until the date on which the shares are transferred to you pursuant hereto. To the extent that cash dividends are otherwise paid with respect to shares of B&W common stock, dividend equivalents will be credited with respect to the shares underlying the RSUs and shall be deferred (with no earnings accruing) until and paid contingent upon the vesting of the related RSUs and paid at the same time the underlying shares are transferred to you.

Taxes

You will realize income in connection with this RSU grant in accordance with the tax laws of the jurisdiction that is applicable to you. You should consult your tax advisor as to the federal and/or state income tax consequences associated with this RSU grant as it relates to your specific circumstances.

By acceptance of this letter, you agree that any amount which B&W is required to withhold on your behalf, including state income tax and FICA withholding, in connection with income realized by you under this grant or as otherwise required under applicable law will be satisfied by withholding whole units or shares having an aggregate fair market value as near equal in value but not exceeding the amount of such required tax withholding, unless the Committee determines to satisfy the statutory minimum withholding obligation by another method permitted by the Plan.

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Regardless of the withholding method, you will promptly pay to B&W the amount of income tax which B&W is required to withhold in connection with the income realized by you in connection with this grant and, unless prohibited by applicable law, that you hereby authorize B&W to withhold such amount, in whole or in part, from subsequent salary payments, without further notice to you.

Transferability

RSUs granted hereunder are non-transferable other than by will or by the laws of descent and distribution or pursuant to a qualified domestic relations order.

Securities and Exchange Commission Requirements

If you are a Section 16 insider, this type of transaction must be reported on a Form 4 before the end of the second (2^nd) business day following the Date of Grant. Please be aware that if you are going to reject the grant, you should do so immediately after the Date of Grant to avoid potential Section 16 liability. Please advise Kathy Peres and Angie Winter immediately by e-mail, fax or telephone if you intend to reject this grant. Absent such notice of rejection, B&W will prepare and file the required Form 4 on your behalf within the required two business day deadline.

Those of you covered by these requirements will have already been advised of your status. Others may become Section 16 insiders at some future date, in which case reporting will be required at that time. If Section 16 applies to you, you are also subject to Rule 144. This Rule is applicable only when the shares are sold, so you need not take any action under Rule 144 at this time.

Clawback Provisions

Recovery of RSUs. In the event that B&W is required to prepare an accounting restatement due to the material noncompliance of B&W with any financial reporting requirement under the U.S. federal securities laws as a result of fraud (a “Restatement”) and the Board reasonably determines that you knowingly engaged in the fraud, B&W will have the right to recover the RSUs granted during the three-year period preceding the date on which the Board or B&W, as applicable, determines it is required to prepare the Restatement (the “Three-Year Period”), or vested in whole or in part during the Three-Year Period, to the extent of any excess of what would have been granted to or would have vested for you under the Restatement.

Recovery Process. In the event a Restatement is required, the Board, based upon a recommendation by the Committee, will (a) review the RSUs either granted or vested in whole or in part during the Three-Year Period and (b) in accordance with the provisions of this Agreement and the Plan, will take reasonable action to seek recovery of the amount of such RSUs in excess of what would have been granted to or would have vested for you under the Restatement (but in no event more than the total amount of such RSUs), as such excess amount is reasonably determined by the Board in its sole discretion, in compliance with Section 409A of the Code. There shall be no duplication of recovery under Article 19 of the Plan and any of 15 U.S.C. Section 7243 (Section 304 of The Sarbanes-Oxley Act of 2002) and Section 10D of the Exchange Act. The clawback provisions of this Agreement are in addition to the forfeiture provisions contained under the heading “Forfeiture of RSUs” above.

Other Information

Neither the action of B&W in establishing the Plan, nor any action taken by it, by the Committee or by your employer, nor any provision of the Plan or this Agreement shall be construed as conferring upon you the right to be retained in the employ of B&W.

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EX-10.19

Exhibit 10.19

2013 PERFORMANCE RESTRICTED STOCK UNITS

GRANT AGREEMENT

Effective [insert date], 2013 (the “Date of Grant”), the Compensation Committee of the Board of Directors (the “Committee”) of The Babcock & Wilcox Company ( “B&W”) awarded you a grant of performance-based restricted stock units (“Performance RSUs”) under the 2010 Long-Term Incentive Plan of B&W, as amended and restated February 22, 2011 (the “Plan”). The provisions of the Plan are incorporated herein by reference.

Any reference or definition contained in this Agreement shall, except as otherwise specified, be construed in accordance with the terms and conditions of the Plan and all determinations and interpretations made by the Committee with regard to any question arising hereunder or under the Plan shall be binding and conclusive on you and your legal representatives and beneficiaries. The term “B&W” as used in this Agreement with reference to employment shall include subsidiaries of B&W (including unconsolidated joint ventures). Whenever the words “you or your” are used in any provision of this Agreement under circumstances where the provision should logically be construed to apply to the beneficiary, estate, or personal representative, to whom any rights under this Agreement may be transferred by will or by the laws of descent and distribution, it shall be deemed to include such person.

Performance RSUs

Performance RSU Award. You have been awarded an initial number of performance-based restricted stock units shown on the attached Notice of Grant (the “Initial Performance RSUs”), which notice is incorporated herein by reference. These Performance RSUs represent a right to receive shares of B&W common stock, calculated as described below, provided the applicable performance measures and vesting requirements set forth in this Agreement have been satisfied. No shares are awarded or issued to you on the Date of Grant.

Vesting Requirements. Subject to the “Forfeiture of Performance RSUs” provision below, Performance RSUs do not provide you with any rights or interest therein until they become vested under one of the following circumstances (each a “Vesting Date”):

• on the third anniversary of the Date of Grant, provided you are still employed by B&W (with the number in which you vest determined as described in the “Number of Performance RSUs” provision below);

• 100% of the Initial Performance RSUs shall become vested prior to the third anniversary of the Date of Grant on the earliest to occur of: (1) the date of termination of your employment from B&W due to death, (2) your disability (as defined in the Plan) or (3) the date a change in control (as defined in the Plan) occurs; and

• the Committee may provide for additional vesting under other circumstances, in its sole discretion.

Forfeiture of Performance RSUs. Except in connection with a Retirement below, Performance RSUs which are not or do not become vested upon your termination of employment for any reason shall, coincident therewith, be forfeited and be of no force and effect.

In the event you terminate employment prior to the third anniversary of the Date of Grant due to Retirement, 25% of the Initial Performance RSUs will remain in effect provided your termination date is on or after the first anniversary of the Date of Grant but prior to the second anniversary, and 50% of the Initial Performance RSUs will remain in effect provided your termination date is on or after the second anniversary of the Date of Grant but prior to the third anniversary. The number of Performance RSUs that will vest pursuant to the preceding sentence will be determined by multiplying (a) the total number of Performance RSUs that would have vested under this Agreement based on actual performance had you remained employed until the third anniversary of the Date of Grant by (b) the applicable percentage from the preceding sentence.

For purposes of this Agreement, “Retirement” means a voluntary termination of employment after attaining age 60 and completing 10 years of service with B&W, or an involuntary termination due to a reduction in force. For purposes of this Agreement, a reduction in force shall mean a termination of employment due to elimination of a previously required position or previously required services, or due to the consolidation of departments, abandonment of plants or offices, technological change or declining business activities, where such termination is intended to be permanent; or under other circumstances which the Committee, in accordance with standards uniformly applied with respect to all similarly situated employees, designates as a reduction in force.

In the event that (a) you are convicted of (i) a felony or (ii) a misdemeanor involving fraud, dishonesty or moral turpitude, or (b) you engage in conduct that adversely affects or may reasonably be expected to adversely affect the business reputation or economic interests of B&W, as determined in the sole judgment of the Committee, then all Performance RSUs and all rights or benefits awarded to you under this grant of Performance RSUs are forfeited, terminated and withdrawn immediately upon such conviction or notice of such determination. The Committee shall have the right to suspend any and all rights or benefits awarded to you hereunder pending its investigation and final determination with regard to such matters. The forfeiture provisions of this paragraph are in addition to the paragraphs under the heading “Clawback Provisions” below.

Number of Performance RSUs. Except as otherwise provided in this Agreement and subject to adjustments permitted by the Plan, the number of Performance RSUs in which you will vest under this Agreement, if any, will be determined by multiplying (a) one-half of the sum of (i) the vested percentage applicable to Return on Invested Capital (“ROIC”) plus (ii) the vested percentage applicable to diluted Earnings Per Share (“EPS”) by (b) the number of Initial Performance RSUs. The maximum number of Performance RSUs in which you can vest is 200% of your Initial Performance RSUs and the minimum number of Performance RSUs in which you can vest is 0% of your Initial Performance RSUs.

- 2 -

The vested percentage applicable to ROIC and EPS will each be determined over the Performance Period as illustrated in the schedules set forth below. For purposes of this Agreement, the “Performance Period” means the period beginning on January 1, 2013 and ending on December 31, 2015.

Calculating ROIC and EPS. Except as otherwise described below, the component values used to calculate ROIC and EPS will be determined in accordance with U.S. generally accepted accounting principles excluding (1) any changes in accounting standards imposed on or adopted by B&W after the Date of Grant, (2) the expenses related to the implementation of B&W’s Global Competitiveness Initiative, (3) any pension accounting mark-to-market adjustment and (4) all acquisition expenses for any transaction with expenses exceeding $5 million.

Return on Invested Capital (ROIC)

The vested percentage applicable to ROIC will be determined based on B&W’s average annual ROIC (as calculated below) (“Average ROIC”) for the Performance Period in accordance with the following schedule:

Average ROIC	ROIC Vested Percentage
[insert threshold ROIC]		50	%
[insert target ROIC]		100	%
[insert maximum ROIC]		200	%

Vested percentages between the amounts shown will be calculated by linear interpolation. The vested percentage applicable to ROIC will be 0% if the Average ROIC for the Performance Period is below [insert threshold]%. In no event will the vested percentage applicable to ROIC be greater than 200%.

ROIC will be calculated quarterly and the ROIC for any calendar year during the Performance Period will equal the sum of the four applicable quarterly ROIC calculations. Average ROIC will equal the sum of the three annual ROIC calculations during the Performance Period divided by three.

For purposes of this Agreement, the term “ROIC” is a ratio measure of B&W’s net income in relation to B&W’s invested capital, using the formula set forth below. For purposes of determining ROIC, net income is pre-tax income less tax expense. Tax expense will be based on B&W’s normal, weighted average effective tax rate for the jurisdictions in which it is operating for the applicable periods. Invested capital is B&W’s total assets less current liabilities. Current liabilities include any liabilities that are due within one calendar year and will be defined based on B&W’s consolidated balance sheet applicable to the applicable period.

- 3 -

For purposes of the ROIC calculation: Net Income will exclude mPower development expenses (less applicable taxes) and Invested Capital will include cumulative mPower development expenses from January 1, 2011 through the end of the Performance Period. mPower development expenses is defined below.

Diluted Earnings Per Share (EPS)

The vested percentage applicable to EPS will be determined based on B&W’s cumulative EPS (as calculated below) (“Cumulative EPS”) for the Performance Period in accordance with the following schedule:

Cumulative EPS	EPS Vested Percentage
[insert threshold EPS]		50	%
[insert target EPS]		100	%
[insert maximum EPS]		200	%

Vested percentages between the amounts shown will be calculated by linear interpolation. The vested percentage applicable to EPS will be 0% if the Cumulative EPS for the Performance Period is below $[insert threshold EPS]. In no event will the vested percentage applicable to EPS be greater than 200%.

EPS will be calculated for each calendar year during the Performance Period and Cumulative EPS for the Performance Period will equal the sum of the three applicable annual EPS calculations.

For purposes of this Agreement, the term “EPS” means B&W’s net income attributable to stockholders of common stock excluding mPower development expenses (less applicable taxes) for the applicable period divided by B&W’s weighted average diluted shares outstanding for the applicable period. For purposes of determining EPS, net income attributable to stockholders of common stock is defined as “Net Income Attributable to The Babcock & Wilcox Company” on B&W’s Consolidated Statement of Income. Diluted shares outstanding will include all basic shares outstanding and any other dilutive securities for the period. If any securities are dilutive, the impact on the number of outstanding shares will be included in the denominator and the related income statement impact of the security will be removed from the numerator.

WACSO represents weighted average common stock outstanding.

For purposes of this Agreement, “mPower development expenses” includes all expenses related to the research and development of mPower plus any applicable selling, general and administrative expenses and any associated operating income. If mPower produces any associated operating income, such operating income will act to reduce the amount of mPower development expenses.

- 4 -

Settlement of Performance RSUs. You (or your beneficiary, if applicable) will receive one share of B&W common stock for each Performance RSU that vests under this Agreement. Shares shall be distributed as soon as administratively practicable after the Settlement Date, but in no event later than March 15 following the end of the calendar year in which the Settlement Date occurs. For purposes of this Agreement, “Settlement Date” means either: (a) the applicable Vesting Date or, in the event you made a permitted deferral election pursuant to the Plan with respect to this grant, (b) the date(s) of the applicable distribution event in accordance with such deferral election.

Dividend, Voting Rights and Other Rights. You shall have no rights of ownership in the shares of B&W common stock underlying the Performance RSUs and shall have no right to vote such shares until the date on which the shares are transferred to you pursuant hereto. To the extent that cash dividends are otherwise paid with respect to shares of B&W common stock, dividend equivalents will be credited with respect to the shares underlying the Performance RSUs and shall be deferred (with no earnings accruing) until and paid contingent upon the vesting of the related Performance RSUs and paid at the same time the underlying shares are transferred to you.

Taxes

You will realize income in connection with this Performance RSUs grant in accordance with the tax laws of the jurisdiction that is applicable to you. You should consult your tax advisor as to the federal and/or state income tax consequences associated with this Performance Share grant as it relates to your specific circumstances.

By acceptance of this letter, you agree that any amount which B&W is required to withhold on your behalf, including state income tax and FICA withholding, in connection with income realized by you under this grant or as otherwise required under applicable law will be satisfied by withholding whole units or shares having an aggregate fair market value as near equal in value but not exceeding the amount of such required tax withholding, unless the Committee determines to satisfy the statutory minimum withholding obligation by another method permitted by the Plan.

Regardless of the withholding method, you will promptly pay to B&W the amount of income tax which B&W is required to withhold in connection with the income realized by you in connection with this grant and, unless prohibited by applicable law, that you hereby authorize B&W to withhold such amount, in whole or in part, from subsequent salary payments, without further notice to you.

Transferability

Performance RSUs granted hereunder are non-transferable other than by will or by the laws of descent and distribution or pursuant to a qualified domestic relations order.

- 5 -

Securities and Exchange Commission Requirements

If you are a Section 16 insider, this grant of Performance RSUs is not reportable on a Form 4 unless and until they become vested. At that time, the number of Performance RSUs ultimately awarded to you must be reported on a Form 4 before the end of the second (2^nd) business day following the Vesting Date, as applicable. Please be aware that if you are going to reject the grant, you should do so immediately after the Date of Grant. Please advise Kathy Peres or Angie Winter immediately by e-mail, fax or telephone if you intend to reject this grant.

Those of you covered by these requirements will have already been advised of your status. Others may become Section 16 insiders at some future date, in which case reporting will be required in the same manner noted above. If Section 16 applies to you, you are also subject to Rule 144. This Rule is applicable only when the shares are sold, so you need not take any action under Rule 144 at this time.

Clawback Provisions

Recovery of Performance RSUs. In the event that B&W is required to prepare an accounting restatement due to the material noncompliance of B&W with any financial reporting requirement under the U.S. federal securities laws as a result of fraud (a “Restatement”) and the Board reasonably determines that you knowingly engaged in the fraud, B&W will have the right to recover the Performance RSUs granted during the three-year period preceding the date on which the Board or B&W, as applicable, determines it is required to prepare the Restatement (the “Three-Year Period”), or vested in whole or in part during the Three-Year Period, to the extent of any excess of what would have been granted to or would have vested for you under the Restatement.

Recovery Process. In the event a Restatement is required, the Board, based upon a recommendation by the Committee, will (a) review the Performance RSUs either granted or vested in whole or in part during the Three-Year Period and (b) in accordance with the provisions of this Agreement and the Plan, will take reasonable action to seek recovery of the amount of such Performance RSUs in excess of what would have been granted to or would have vested for you under the Restatement (but in no event more than the total amount of such Performance RSUs), as such excess amount is reasonably determined by the Board in its sole discretion, in compliance with Section 409A of the Code. There shall be no duplication of recovery under Article 19 of the Plan and any of 15 U.S.C. Section 7243 (Section 304 of The Sarbanes-Oxley Act of 2002) and Section 10D of the Exchange Act.

Other Information

Neither the action of B&W in establishing the Plan, nor any action taken by it, by the Committee or by your employer, nor any provision of the Plan or this Agreement shall be construed as conferring upon you the right to be retained in the employ of B&W or any of its subsidiaries or affiliates.

- 6 -

EX-18

EXHIBIT 18

February 27, 2013

The Babcock & Wilcox Company

13024 Ballantyne Corporate Place

Suite 700

Charlotte, NC 28277

Dear Sirs/Madams:

We have audited the financial statements of The Babcock & Wilcox Company and subsidiaries (the “Company”) as of December 31, 2012 and 2011, and for each of the three years in the period ended December 31, 2012, included in your Annual Report on Form 10-K to the Securities and Exchange Commission and have issued our report thereon dated February 27, 2013, which expresses an unqualified opinion and includes an explanatory paragraph concerning the Company’s election to change its methods of accounting for defined benefit pension and other postretirement benefit plan costs during 2012. Note 1 to such financial statements contains a description of your adoption during the year ended December 31, 2012 of changes in accounting principles for recognizing actuarial gains and losses for all pension and postretirement benefit plans from a corridor amortization method (Canadian plans) and an amortization method without a corridor (domestic plans) to immediate recognition. In our judgment, such changes are to alternative accounting principles that are preferable under the circumstances.

Yours truly,

/S/ Deloitte & Touche LLP

Charlotte, North Carolina

EX-21.1

EXHIBIT 21.1

THE BABCOCK & WILCOX COMPANY

SIGNIFICANT SUBSIDIARIES OF THE REGISTRANT

YEAR ENDED DECEMBER 31, 2012

NAME OF COMPANY	JURISDICTION OF ORGANIZATION	PERCENTAGE OF OWNERSHIP INTEREST
The Babcock & Wilcox Investment Company	Delaware		100
Babcock & Wilcox Power Generation Group, Inc.	Delaware		100
Babcock & Wilcox Canada Ltd.	Canada		100
BWX Technologies, Inc.	Delaware		100
Babcock & Wilcox Nuclear Operations Group, Inc.	Delaware		100
Babcock & Wilcox Nuclear Energy, Inc.	Delaware		100
Nuclear Fuel Services, Inc.	Delaware		100
Generation mPower LLC	Delaware		90
Babcock & Wilcox Commercial Power, Inc.	Delaware		100
Babcock & Wilcox Modular Reactors, LLC	Delaware		100
Babcock & Wilcox mPower, Inc.	Delaware		100

The subsidiaries omitted from the foregoing list, considered in the aggregate as a single subsidiary, do not constitute a significant subsidiary.

EX-23.1

EXHIBIT 23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Registration Statement No. 333-168687 on Form S-8 of our reports dated February 27, 2013, relating to the consolidated and combined financial statements of The Babcock & Wilcox Company (which report expresses an unqualified opinion and includes explanatory paragraphs regarding a change in the Babcock & Wilcox Company’s method of recognizing actuarial gains and losses for pension and other postretirement benefit plans for the year ended December 31, 2012 and a change to the operation of The Babcock & Wilcox Company as a subsidiary of McDermott International, Inc. in a portion of 2010), and the effectiveness of The Babcock & Wilcox Company’s internal control over financial reporting, appearing in this Annual Report on Form 10-K of The Babcock & Wilcox Company for the year ended December 31, 2012.

/s/ DELOITTE & TOUCHE LLP

Charlotte, North Carolina

February 27, 2013

EX-31.1

EXHIBIT 31.1

CERTIFICATIONS

I, E. James Ferland, certify that:

1. I have reviewed this annual report on Form 10-K of The Babcock & Wilcox Company for the year ended December 31, 2012;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the Company’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a. all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b. any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

February 27, 2013

/s/ E. James Ferland

E. James Ferland

President and Chief Executive Officer

EX-31.2

EXHIBIT 31.2

I, Anthony S. Colatrella, certify that:

1. I have reviewed this annual report on Form 10-K of The Babcock & Wilcox Company for the year ended December 31, 2012;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the Company’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a. all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b. any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

February 27, 2013

/s/ Anthony S. Colatrella

Anthony S. Colatrella

Senior Vice President and Chief Financial Officer

EX-32.1

EXHIBIT 32.1

THE BABCOCK & WILCOX COMPANY

Certification Pursuant to

Section 906 of the Sarbanes-Oxley Act of 2002

(Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code)

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code), I, E. James Ferland, President and Chief Executive Officer of The Babcock & Wilcox Company, a Delaware corporation (the “Company”), hereby certify, to my knowledge, that:

(1) the Company’s Annual Report on Form 10-K for the year ended December 31, 2012 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: February 27, 2013	/s/ E. James Ferland
	E. James Ferland
	President and Chief Executive Officer

EX-32.2

EXHIBIT 32.2

THE BABCOCK & WILCOX COMPANY

Certification Pursuant to

Section 906 of the Sarbanes-Oxley Act of 2002

(Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code)

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code), I, Anthony S. Colatrella, Senior Vice President and Chief Financial Officer of The Babcock & Wilcox Company, a Delaware corporation (the “Company”), hereby certify, to my knowledge, that:

(1) the Company’s Annual Report on Form 10-K for the year ended December 31, 2012 (the “Report”) fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: February 27, 2013	/s/ Anthony S. Colatrella
	Anthony S. Colatrella
	Senior Vice President and Chief Financial Officer

EX-95

Exhibit 95

Mine or Operating Name / MSHA Identification Number

Section 104 S&S Citations (#)

Section 104(b) Orders (#)

Section 104(d) Citations and Orders (#)

Section 110(b)(2) Violations (#)

Section 107(a) Orders (#)

Total Dollar Value of MSHA Assessments Proposed ($)

Total Number of Mining Related Fatalities (#)

Received Notice of Pattern of Violations Under Section 104(e) (yes/no)

Received Notice of Potential to Have Pattern Under Section 104(e) (yes/no)

Legal Actions Pending as of 12/31/2012 (#)

Legal Actions Initiated During Period (#)

Legal Actions Resolved During Period (#)

Revloc Refuse Site ID # 3608032

0

0

0

0

0

0

0

No

No

0

0

0

XML

Derivative Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2012

Summary Of Derivative Financial Instruments

The following tables summarize our derivative financial instruments at December 31, 2012 and 2011:

	Asset and Liability Derivatives
	December 31,
	2012		2011
	(In thousands)
Derivatives Designated as Hedges:
Foreign Exchange Contracts:
Location
Accounts receivable-other	$	2,251	$	1,760
Other assets	$	3,777	$	3,792
Accounts payable	$	1,893	$	1,238
Other liabilities	$	29	$	610
Derivatives Not Designated as Hedges:
Foreign Exchange Contracts:
Location
Other assets	$	191	$	—
Accounts payable	$	962	$	520
Other liabilities	$	—	$	664
Stock Warrants:
Location
Other assets	$	317	$	877

Schedule Of Effect Of Derivative Instruments On The Statements Of Financial Performance

The effects of derivatives on our financial statements are outlined below:

	December 31,
	2012			2011
	(In thousands)
Derivatives Designated as Hedges:
Cash Flow Hedges:
Foreign Exchange Contracts:
Amount of gain (loss) recognized in other comprehensive income	$	2,031		$	(1,224	)
Income (loss) reclassified from accumulated other comprehensive loss into income: effective portion
Location
Revenues	$	(1,082	)	$	4,128
Cost of operations	$	3,833		$	(2,350	)
Other-net	$	(24	)	$	373
Gain (loss) recognized in income: portion excluded from effectiveness testing
Location
Other-net	$	(185	)	$	1,045
Derivatives Not Designated as Hedges:
Forward Contracts:
Gain (loss) recognized in income
Location
Other-net	$	(169	)	$	1,234
Stock Warrants:
Loss recognized
Location
Other-net	$	(560	)	$	(2,419	)

XML

Segment Reporting (Schedule of Revenue Information from Products and Service Lines) (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Revenue from External Customer [Line Items]
Eliminations/Other									$ (26,435)	[1]	$ (73,771)	[1]	$ (18,161)	[1]
Revenues	865,296	807,586	852,585	765,892	800,789	707,622	752,352	691,277	3,291,359	[1],[2]	2,952,040	[1],[2]	2,688,811	[1],[2]
Power Generation [Member]
Revenue from External Customer [Line Items]
Eliminations/Other									7,932		53,852		5,092
Revenues									1,785,959	[1]	1,541,509	[1]	1,424,574	[1]
Power Generation [Member] | New Build Environmental Equipment [Member]
Revenue from External Customer [Line Items]
Revenues									446,514		235,750		277,531
Power Generation [Member] | New Build Steam Generation Systems [Member]
Revenue from External Customer [Line Items]
Revenues									511,201		416,779		386,356
Power Generation [Member] | Aftermarket Services [Member]
Revenue from External Customer [Line Items]
Revenues									841,571		894,677		765,573
Power Generation [Member] | Eliminations/Other [Member]
Revenue from External Customer [Line Items]
Revenues									(13,327)		(5,697)		(4,886)
Nuclear Operations [Member]
Revenue from External Customer [Line Items]
Eliminations/Other									6,015		5,860		4,423
Revenues									1,098,031	[1]	1,043,185	[1]	995,969	[1]
Nuclear Operations [Member] | Eliminations/Other [Member]
Revenue from External Customer [Line Items]
Revenues									6,042		5,673		4,568
Nuclear Operations [Member] | Nuclear Component Program [Member]
Revenue from External Customer [Line Items]
Revenues									1,086,081		1,025,838		986,952
Nuclear Operations [Member] | Commercial Operations [Member]
Revenue from External Customer [Line Items]
Revenues									5,908		11,674		4,449
Technical Services [Member]
Revenue from External Customer [Line Items]
Eliminations/Other									3,496		2,155		2,438
Revenues									107,851	[1]	119,711	[1]	90,147	[1]
Technical Services [Member] | Eliminations/Other [Member]
Revenue from External Customer [Line Items]
Revenues
Technical Services [Member] | Commercial Operations [Member]
Revenue from External Customer [Line Items]
Revenues									20,819		29,708		28,862
Technical Services [Member] | Nuclear Environmental Services [Member]
Revenue from External Customer [Line Items]
Revenues									78,228		76,267		48,351
Technical Services [Member] | Management & Operation Contracts Of U.S. Government Facilities [Member]
Revenue from External Customer [Line Items]
Revenues									8,804		13,736		12,934
Nuclear Energy [Member]
Revenue from External Customer [Line Items]
Eliminations/Other									8,992		11,904		6,208
Revenues									325,953	[1]	321,406	[1]	196,282	[1]
Nuclear Energy [Member] | Eliminations/Other [Member]
Revenue from External Customer [Line Items]
Revenues									258		1,960		2
Nuclear Energy [Member] | Nuclear Services [Member]
Revenue from External Customer [Line Items]
Revenues									158,365		151,118		119,244
Nuclear Energy [Member] | Nuclear Equipment Operations [Member]
Revenue from External Customer [Line Items]
Revenues									134,011		122,789		72,336
Nuclear Energy [Member] | Nuclear Projects [Member]
Revenue from External Customer [Line Items]
Revenues									$ 33,319		$ 45,539		$ 4,700

[1] Segment revenues are net of the following intersegment transfers and other adjustments:

[2] We allocate geographic revenues based on the location of the customer's operations.

XML

Basis Of Presentation And Significant Accounting Policies (Schedule Of Intangible Assets) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Amortized intangible assets	$ 72,863	$ 98,919	$ 93,255
Accumulated amortization	(30,312)	(41,013)	(32,786)
Net amortized intangible assets	42,551	57,906	60,469
Unamortized intangible assets	45,135	45,135	45,135
Customer Relationships [Member]
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Amortized intangible assets	36,644	40,051	37,167
Accumulated amortization	(11,173)	(8,618)	(6,026)
Acquired backlog [Member]
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Amortized intangible assets	2,979	22,435	19,335
Accumulated amortization	(1,457)	(17,040)	(12,701)
Tradename [Member]
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Amortized intangible assets	11,945	15,169	12,291
Accumulated amortization	(6,422)	(6,509)	(4,260)
Unpatented Technology [Member]
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Amortized intangible assets	6,422	6,402	5,902
Accumulated amortization	(2,682)	(2,033)	(1,407)
Patented Technology [Member]
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Amortized intangible assets	6,961	6,961	6,625
Accumulated amortization	(4,235)	(3,219)	(2,096)
All Other [Member]
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Amortized intangible assets	7,912	7,901	11,935
Accumulated amortization	(4,343)	(3,594)	(6,296)
NRC category 1 license [Member]
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Unamortized intangible assets	43,830	43,830	43,830
Trademarks and trade names [Member]
Schedule Of Amortized And Unamortized Intangible Assets [Line Items]
Unamortized intangible assets	$ 1,305	$ 1,305	$ 1,305

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Basis of Presentation and Significant Accounting Policies (Accumulated Other Comprehensive Loss) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Accumulated Other Comprehensive Income Loss [Line Items]
Currency translation adjustments	$ 40,899	$ 36,626
Net unrealized gain on investments	597	201
Net unrealized gain on derivative financial instruments	2,103	2,717
Unrecognized prior service cost on benefit obligations	(10,871)	(12,718)
Accumulated other comprehensive income	$ 32,728	$ 26,826

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Effect Of Accounting Change - Impact of Adjustments on Consolidated and Combined Results and Financial Position (Detail) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Consolidated and Combined Statements of Income
Cost of operations									$ 2,461,205	$ 2,384,154	$ 2,032,347
Selling, general and administrative expenses									428,293	447,561	412,486
Provision for Income Taxes	0								101,861	23,880	80,005
Net income									217,557	70,618	140,203
Net income attributable to The Babcock & Wilcox Company	39,071	51,443	77,231	59,950	(63,009)	56,742	58,665	25,921	227,695	78,319	139,939
Net income attributable to The Babcock & Wilcox Company	$ 0.33	$ 0.43	$ 0.65	$ 0.51	$ (0.53)	$ 0.48	$ 0.50	$ 0.22	$ 1.92	$ 0.67	$ 1.20
Net Income Attributable to The Babcock & Wilcox Company	$ 0.33	$ 0.43	$ 0.65	$ 0.50	$ (0.53)	$ 0.48	$ 0.50	$ 0.22	$ 1.91	$ 0.66	$ 1.19
Consolidated and Combined Statements of Comprehensive Income
Unrecognized losses arising during the period									434	1,205	551
Amortization of losses included in net income									(2,281)	(2,487)	(2,386)
Consolidated Balances Sheets:
Capital in excess of par value	713,257				676,952				713,257	676,952
Retained earnings	349,063				130,890				349,063	130,890
Accumulated other comprehensive income (loss)	32,728				26,826				32,728	26,826
Consolidated and Combined Statements of Cash Flows:
Net income									217,557	70,618	140,203
Provision for (benefit from) deferred taxes									43,038	(19,200)	31,168
Recognition of losses and prior service cost for pension and postretirement plans									(35,480)	(219,508)	(95,547)
New Method [Member]
Consolidated and Combined Statements of Income
Cost of operations									2,461,205	2,384,154	2,032,347
Selling, general and administrative expenses									428,293	447,561	412,486
Other income (expense)-net									(24,927)	2,028	(16,896)
Provision for Income Taxes									101,861	23,880	80,005
Net income									217,557	70,618	140,203
Net income attributable to The Babcock & Wilcox Company									227,695	78,319	139,939
Net income attributable to The Babcock & Wilcox Company									$ 1.92	$ 0.67	$ 1.20
Net Income Attributable to The Babcock & Wilcox Company									$ 1.91	$ 0.66	$ 1.19
Consolidated and Combined Statements of Comprehensive Income
Unrecognized losses arising during the period									(434)	(1,205)	(551)
Amortization of losses included in net income									2,281	2,487	2,386
Consolidated Balances Sheets:
Capital in excess of par value	713,257				676,952				713,257	676,952
Retained earnings	349,063				130,890				349,063	130,890
Accumulated other comprehensive income (loss)	32,728				26,826				32,728	26,826
Consolidated and Combined Statements of Cash Flows:
Net income									217,557	70,618	140,203
Provision for (benefit from) deferred taxes									43,038	(19,200)	31,168
Recognition of losses and prior service cost for pension and postretirement plans									35,480	219,508	95,547
Previously Reported Or Historical [Member]
Consolidated and Combined Statements of Income
Cost of operations									2,500,858	2,278,208	2,024,034
Selling, general and administrative expenses									434,673	413,210	405,682
Other income (expense)-net									(24,903)	2,168	(16,400)
Provision for Income Taxes									84,495	72,982	82,294
Net income									188,914	161,953	153,526
Net income attributable to The Babcock & Wilcox Company									199,052	169,654	153,262
Net income attributable to The Babcock & Wilcox Company									$ 1.68	$ 1.44	$ 1.32
Net Income Attributable to The Babcock & Wilcox Company									$ 1.67	$ 1.43	$ 1.30
Consolidated and Combined Statements of Comprehensive Income
Unrecognized losses arising during the period									(21,486)	(140,436)	(62,059)
Amortization of losses included in net income									51,976	50,382	50,571
Consolidated Balances Sheets:
Capital in excess of par value	1,143,275				1,106,971				1,143,275	1,106,971
Retained earnings	455,855				266,325				455,855	266,325
Accumulated other comprehensive income (loss)	(504,082)				(538,628)				(504,082)	(538,628)
Consolidated and Combined Statements of Cash Flows:
Net income									188,914	161,953	153,526
Provision for (benefit from) deferred taxes									25,672	29,902	33,457
Recognition of losses and prior service cost for pension and postretirement plans									$ 78,050	$ 79,070	$ 79,935

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Income Taxes (Reconciliation Of U.S. Statutory Federal Tax Rate To Consolidated And Combined Effective Tax Rate) (Detail)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Reconciliation Of Effective Income Tax Rate [Line Items]
U.S. federal statutory (benefit) rate	35.00%	35.00%	35.00%
State and local income taxes	4.30%	6.40%	3.40%
Foreign rate differential	(4.10%)	(11.80%)	(5.30%)
Foreign operations	0.50%	6.40%	0.40%
Tax credits	(2.50%)	(46.80%)	(4.90%)
Dividends and deemed dividends from affiliates	2.30%	38.70%	9.10%
Valuation allowances	3.40%	7.60%	(2.60%)
Uncertain tax positions	(9.00%)	(2.80%)	1.30%
Non-deductible expenses	1.30%	5.50%	1.10%
Additional spin related benefit		(4.60%)
Manufacturing deduction	(1.30%)	(3.60%)	(1.60%)
Minority interest	1.10%	3.20%
Other	0.90%	(7.90%)	0.40%
Effective tax rate	31.90%	25.30%	36.30%

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Basis of Presentation and Significant Accounting Policies (Changes in Carrying Amount of Intangible Assets) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Finite-Lived Intangible Assets [Line Items]
Balance at beginning of period	$ 103,041	$ 105,604	$ 103,379
Business acquisitions & adjustments	(1,746)	9,100	14,280
Amortization expense	(11,010)	(11,545)	(11,679)
Impairment charge	(3,216)
Foreign currency translation adjustments and other	617	(118)	(376)
Balance at end of period	$ 87,686	$ 103,041	$ 105,604

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Pension Plans And Postretirement Benefits (Narrative) (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Other comprehensive loss as components of net periodic benefit cost for pension benefit in the current fiscal year	$ 3.6
Other comprehensive loss as components of net periodic benefit cost for other benefit in the current fiscal year	(0.1)
Other comprehensive loss as components of net periodic benefit cost for pension benefit in the next fiscal year	3.7
Other comprehensive loss as components of net periodic benefit cost for other benefit in the next fiscal year	(0.3)
Expected return on plan assets	7.20%
Percentage of investment return on domestic plan assets	12.00%	7.00%
Term of written notice required for termination from plan (in days)	90 days
Contributions as a percentage of total contributions to the Boilermaker Plan	5.00%
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	7.08%	8.24%
Percentage of total assets	89.00%
Voluntary Employees' Beneficiary Association Trust [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of total assets	85.00%
SERP Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	0.6	0.3	0.7
Thrift Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of matching contribution by employer	50.00%
Participants' contributions as a percentage of compensation	6.00%
MII Thrift Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of matching contribution by employer	50.00%
Participants' contributions as a percentage of compensation	6.00%
Thrift Plan And MII Thrift Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	24.2	22.1	19.7
Restoration Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	0.1
Canadian Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contributions	$ 0.5

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Derivative Financial Instruments (Summary Of Derivative Financial Instruments) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Derivatives Designated As Hedges [Member] | Foreign Exchange Contracts [Member] | Accounts Receivable-Other [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	$ 2,251	$ 1,760
Derivatives Designated As Hedges [Member] | Foreign Exchange Contracts [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	3,777	3,792
Derivatives Designated As Hedges [Member] | Foreign Exchange Contracts [Member] | Accounts Payable [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	1,893	1,238
Derivatives Designated As Hedges [Member] | Foreign Exchange Contracts [Member] | Other Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	29	610
Derivatives Not Designated as Hedges [Member] | Foreign Exchange Contracts [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	191
Derivatives Not Designated as Hedges [Member] | Foreign Exchange Contracts [Member] | Accounts Payable [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	962	520
Derivatives Not Designated as Hedges [Member] | Foreign Exchange Contracts [Member] | Other Liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives		664
Derivatives Not Designated as Hedges [Member] | Stock Warrants [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	$ 317	$ 877

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Basis Of Presentation And Significant Accounting Policies (Contracts In Progress And Advance Billings) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Contracts In Progress Costs And Earnings [Line Items]
Costs incurred less costs of revenue recognized	$ 135,972	$ 135,513
Revenues recognized less billings to customers	180,546	179,773
Contracts In Progress	316,518	315,286
Billings to customers less revenues recognized	541,983	492,106
Costs incurred less costs of revenue recognized	(69,696)	(53,353)
Advance Billings on Contracts	$ 472,287	$ 438,753

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Income Taxes (Tables)

12 Months Ended

Dec. 31, 2012

Reconciliation Of Unrecognized Tax Benefits

A reconciliation of unrecognized tax benefits follows:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	32,357		$	36,342		$	11,842
Increases based on tax positions taken in the current year		980			1,171			6,550
Increases based on tax positions taken in the prior years		65			3,269			343
Increases due to positions assumed at spin-off		—			—			24,181
Decreases based on tax positions taken in the prior years		(3,114	)		(4,329	)		(1,442	)
Decreases due to settlements with tax authorities		(1,101	)		(1,073	)		(5,132	)
Decreases due to lapse of applicable statute of limitation		(24,700	)		(3,023	)		—
Balance at end of period	$	4,487		$	32,357		$	36,342

Components Of Deferred Tax Assets And Liabilities

Significant components of deferred tax assets and liabilities as of December 31, 2012 and 2011 were as follows:

	December 31,
	2012			2011
	(In thousands)
Deferred tax assets:
Pension liability	$	201,229		$	216,248
Accrued warranty expense		26,695			33,412
Accrued vacation pay		13,312			13,269
Accrued liabilities for self-insurance (including postretirement health care benefits)		35,374			41,243
Accrued liabilities for executive and employee incentive compensation		39,483			29,539
Environmental and products liabilities		8,024			7,711
Investments in joint ventures and affiliated companies		16,993			3,704
Long-term contracts		29,807			22,871
Net operating loss carryforward		15,787			22,380
State tax net operating loss carryforward		21,757			22,734
Foreign tax credit carryforward		808			18,292
Other		7,722			8,273
Total deferred tax assets		416,991			439,676
Valuation allowance for deferred tax assets		(19,979	)		(9,354	)
Deferred tax assets		397,012			430,322
Deferred tax liabilities:
Property, plant and equipment		39,016			31,874
Investments in joint ventures and affiliated companies		1,064			791
Long-term contracts		30,571			27,681
Intangibles		24,756			26,365
Other		9,580			8,080
Total deferred tax liabilities		104,987			94,791
Net deferred tax assets	$	292,025		$	335,531

Income Before Provision For Income Taxes

Income before provision for income taxes was as follows:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
U.S.	$	222,840	$	39,417	$	174,242
Other than U.S.		96,578		55,081		45,966
Income before provision for income taxes	$	319,418	$	94,498	$	220,208

Components Of Provision For Income Taxes

The provision for income taxes consisted of:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Current:
U.S. – federal	$	39,784	$	24,591		$	29,191
U.S. – state and local		7,979		7,452			8,029
Other than U.S.		11,060		11,037			11,617
Total current		58,823		43,080			48,837
Deferred:
U.S. – Federal		24,560		(20,066	)		33,541
U.S. – State and local		6,545		5,195			(389	)
Other than U.S.		11,933		(4,329	)		(1,984	)
Total deferred (benefit) provision		43,038		(19,200	)		31,168
Provision for income taxes	$	101,861	$	23,880		$	80,005

Reconciliation Of U.S. Statutory Federal Tax Rate To Consolidated And Combined Effective Tax Rate

The following is a reconciliation of the U.S. statutory federal tax rate (35%) to the consolidated and combined effective tax rate:

	Year Ended December 31,
	2012			2011			2010
U.S. federal statutory (benefit) rate		35.0	%		35.0	%		35.0	%
State and local income taxes		4.3			6.4			3.4
Foreign rate differential		(4.1	)		(11.8	)		(5.3	)
Foreign operations		0.5			6.4			0.4
Tax credits		(2.5	)		(46.8	)		(4.9	)
Dividends and deemed dividends from affiliates		2.3			38.7			9.1
Valuation allowances		3.4			7.6			(2.6	)
Uncertain tax positions		(9.0	)		(2.8	)		1.3
Non-deductible expenses		1.3			5.5			1.1
Additional spin related benefit		—			(4.6	)		—
Manufacturing deduction		(1.3	)		(3.6	)		(1.6	)
Minority interest		1.1			3.2			—
Other		0.9			(7.9	)		0.4
Effective tax rate		31.9	%		25.3	%		36.3	%

Valuation Allowance For Deferred Tax Assets

The following is an analysis of our valuation allowance for deferred tax assets:

	Beginning Balance			Charges To Costs and Expenses			Charged To Other Accounts		Effect Of Spin-Off(1)		Ending Balance
	(In thousands)
Year Ended December 31, 2012	$	(9,354	)		(10,625	)		—		—	$	(19,979	)
Year Ended December 31, 2011	$	(2,205	)		(7,149	)		—		—	$	(9,354	)
Year Ended December 31, 2010	$	(28,701	)		6,904			—		19,592	$	(2,205	)

⁽¹⁾  Effect of spin-off includes state tax valuation allowances distributed to MII in the spin-off.

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Pension Plans And Postretirement Benefits (Weighted Average Assumptions) (Detail)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Weighted average assumptions used to determine net periodic benefit cost, Expected return on plan assets	7.20%
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average assumptions used to determine net periodic benefit obligations, Discount rate	4.09%	4.76%
Weighted average assumptions used to determine net periodic benefit obligations, Rate of compensation increase	2.57%	3.69%
Weighted average assumptions used to determine net periodic benefit cost, Discount rate	4.76%	5.56%
Weighted average assumptions used to determine net periodic benefit cost, Expected return on plan assets	7.08%	8.24%
Weighted average assumptions used to determine net periodic benefit cost, Rate of compensation increase	3.69%	3.69%
Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average assumptions used to determine net periodic benefit obligations, Discount rate	3.43%	4.35%
Weighted average assumptions used to determine net periodic benefit cost, Discount rate	4.34%	4.92%
Weighted average assumptions used to determine net periodic benefit cost, Expected return on plan assets	5.76%	5.76%

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Quarterly Financial Data ( Schedule of Adjustments on Previously Reported Quarterly Results) (Detail) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended																12 Months Ended
	Dec. 31, 2012		Sep. 30, 2012		Jun. 30, 2012		Mar. 31, 2012		Dec. 31, 2011		Sep. 30, 2011		Jun. 30, 2011		Mar. 31, 2011		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Quarterly Financial Data [Line Items]
Operating income(loss)	$ 65,693	[1]	$ 84,399	[1]	$ 110,077	[1]	$ 86,420	[1]	$ (103,444)	[1]	$ 74,912	[1]	$ 82,809	[1]	$ 41,394	[1]	$ 346,589	[2]	$ 95,671	[2]	$ 248,855	[2]
Net income attributable to The Babcock & Wilcox Company	39,071		51,443		77,231		59,950		(63,009)		56,742		58,665		25,921		227,695		78,319		139,939
Net income attributable to The Babcock & Wilcox Company,Basic earnings per common share	$ 0.33		$ 0.43		$ 0.65		$ 0.51		$ (0.53)		$ 0.48		$ 0.50		$ 0.22		$ 1.92		$ 0.67		$ 1.20
Net income attributable to The Babcock & Wilcox Company,Diluted earnings per common share	$ 0.33		$ 0.43		$ 0.65		$ 0.50		$ (0.53)		$ 0.48		$ 0.50		$ 0.22		$ 1.91		$ 0.66		$ 1.19
Adjustment [Member]
Quarterly Financial Data [Line Items]
Operating income(loss)	(12,486)		17,092		20,718		20,709		(196,703)		17,361		19,552		19,493
Net income attributable to The Babcock & Wilcox Company	$ (8,692)		$ 10,922		$ 13,207		$ 13,206		$ (127,281)		$ 11,079		$ 12,456		$ 12,411
Net income attributable to The Babcock & Wilcox Company,Basic earnings per common share	$ (0.07)		$ 0.09		$ 0.11		$ 0.11		$ (1.07)		$ 0.09		$ 0.11		$ 0.10
Net income attributable to The Babcock & Wilcox Company,Diluted earnings per common share	$ (0.07)		$ 0.09		$ 0.11		$ 0.11		$ (1.07)		$ 0.09		$ 0.11		$ 0.11

[1] Includes equity in income of investees.

[2] (2) Included in operating income is the following:

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Long-Term Debt And Notes Payable (Narrative) (Detail) (USD $)	1 Months Ended	12 Months Ended
	May 03, 2010	Dec. 31, 2012	Dec. 31, 2011
Short-term line of credit interest rate		6.60%	7.20%
Amounts due within one year		$ (214,000)	$ (205,000)
Maturity of long-term debt, 2014		200,000
Maturity of long-term debt, 2015		200,000
Maturity of long-term debt, 2016		0
Maturity of long-term debt, 2017		0
Aggregate outstanding amount	700,000,000
Credit facility maturity date	Jun. 08, 2017
Aggregate maximum borrowing capacity	1,000,000,000
Commitment fee		0.25%
Interest rate under the facility, per year		3.75%
Bonds issued and outstanding		468,600,000
Babcock & Wilcox Power Generation Group, Inc [Member]
Aggregate value of bank guarantees		59,400,000
Base-Rate Loans [Member]
Margin added to interest rate		0.50%
Base-Rate Loans [Member] | Federal Funds Rate [Member]
Margin added to interest rate		0.50%
Base-Rate Loans [Member] | 30-Day Eurodollar Rate [Member]
Margin added to interest rate		1.00%
Financial Letter Of Credit [Member]
Letter of credit fee		1.50%
Performance Letter Of Credit [Member]
Letter of credit fee		0.875%
Eurodollar-Rate Loans [Member]
Margin added to interest rate		1.50%
Letters Of Credit [Member]
Aggregate outstanding amount		157,900,000
Aggregate borrowing capacity		$ 542,100,000
Minimum [Member]
Commitment fee		0.225%
Minimum [Member] | Eurodollar-Rate Loans [Member]
Margin added to interest rate		1.25%
Minimum [Member] | Base-Rate Loans [Member]
Margin added to interest rate		0.25%
Minimum [Member] | Financial Letter Of Credit [Member]
Letter of credit fee		1.25%
Minimum [Member] | Performance Letter Of Credit [Member]
Letter of credit fee		0.80%
Maximum [Member]
Commitment fee		0.35%
Maximum [Member] | Eurodollar-Rate Loans [Member]
Margin added to interest rate		2.25%
Maximum [Member] | Base-Rate Loans [Member]
Margin added to interest rate		1.25%
Maximum [Member] | Financial Letter Of Credit [Member]
Letter of credit fee		2.25%
Maximum [Member] | Performance Letter Of Credit [Member]
Letter of credit fee		1.25%

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Capital Stock (Narrative) (Detail) (USD $)	1 Months Ended	12 Months Ended
	Jul. 30, 2010	Dec. 31, 2012
Capital Stock [Line Items]
Percentage of outstanding common stock distributed	100.00%
Common stock split	One share of B&W common stock for every two shares of MII common stock
Common stock distributed to MII shareholders to complete spin-off	116,225,732
Dividend declared		$ 0.08
Common stock at an aggregate purchase price		$ 250,000,000
Common stock repurchased		$ 96,774,000
Common stock repurchased, shares		3,908,684,000,000
Shares of common stock reserved for future issuance		9,111,185

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Basis of Presentation and Significant Accounting Policies (Changes in Carrying Amount of Other Non-Current Assets) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Other Noncurrent Assets [Line Items]
Balance at beginning of period	$ 5,723	$ 8,102	$ 1,898
Additions	4,902	82	9,994
Interest expense - debt issuance costs	(2,157)	(2,461)	(3,790)
Balance at end of period	$ 8,468	$ 5,723	$ 8,102

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Segment Reporting (Schedule Of Revenues By Segment) (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues	$ 865,296	$ 807,586	$ 852,585	$ 765,892	$ 800,789	$ 707,622	$ 752,352	$ 691,277	$ 3,291,359	[1],[2]	$ 2,952,040	[1],[2]	$ 2,688,811	[1],[2]
Adjustments and Eliminations									(26,435)	[2]	(73,771)	[2]	(18,161)	[2]
Adjustments and Eliminations									26,435	[2]	73,771	[2]	18,161	[2]
Power Generation [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues									1,785,959	[2]	1,541,509	[2]	1,424,574	[2]
Adjustments and Eliminations									7,932		53,852		5,092
Adjustments and Eliminations									(7,932)		(53,852)		(5,092)
Nuclear Operations [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues									1,098,031	[2]	1,043,185	[2]	995,969	[2]
Adjustments and Eliminations									6,015		5,860		4,423
Adjustments and Eliminations									(6,015)		(5,860)		(4,423)
Technical Services [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues									107,851	[2]	119,711	[2]	90,147	[2]
Adjustments and Eliminations									3,496		2,155		2,438
Adjustments and Eliminations									(3,496)		(2,155)		(2,438)
Nuclear Energy [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues									325,953	[2]	321,406	[2]	196,282	[2]
Adjustments and Eliminations									8,992		11,904		6,208
Adjustments and Eliminations									$ (8,992)		$ (11,904)		$ (6,208)

[1] We allocate geographic revenues based on the location of the customer's operations.

[2] Segment revenues are net of the following intersegment transfers and other adjustments:

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Pension Plans And Postretirement Benefits (Components Of Net Periodic Benefit Cost) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 46,828	$ 43,495	$ 39,176
Interest cost	122,605	134,927	142,092
Expected return on plan assets	(136,913)	(148,347)	(136,364)
Amortization of prior service cost	3,579	3,721	3,711
Recognized net actuarial loss (gain)	34,496	212,802	106,805
Net periodic benefit cost (income)	70,595	246,598	155,420
Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	1,138	1,143	1,069
Interest cost	5,124	5,805	7,284
Expected return on plan assets	(1,930)	(1,919)	(1,744)
Amortization of prior service cost	(139)	33	28
Recognized net actuarial loss (gain)	(2,456)	2,952	(14,997)
Net periodic benefit cost (income)	$ 1,737	$ 8,014	$ (8,360)

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Pension Plans and Postretirement Benefits (Cash Flows) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012
Domestic Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions to trusts of defined benefit plans, 2013	$ 52,000
Expected benefit payments, 2013	127,558
Expected benefit payments, 2014	133,785
Expected benefit payments, 2015	139,444
Expected benefit payments, 2016	144,617
Expected benefit payments, 2017	149,047
Expected benefit payments, 2018-2022	785,955
Domestic Plans, Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions to trusts of defined benefit plans, 2013	2,082
Expected benefit payments, 2013	12,500
Expected benefit payments, 2014	11,768
Expected benefit payments, 2015	10,581
Expected benefit payments, 2016	9,470
Expected benefit payments, 2017	8,163
Expected benefit payments, 2018-2022	28,708
Foreign Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions to trusts of defined benefit plans, 2013	20,040
Expected benefit payments, 2013	11,389
Expected benefit payments, 2014	12,075
Expected benefit payments, 2015	12,731
Expected benefit payments, 2016	13,671
Expected benefit payments, 2017	14,116
Expected benefit payments, 2018-2022	79,572
Foreign Plans, Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected benefit payments, 2013	596
Expected benefit payments, 2014	621
Expected benefit payments, 2015	613
Expected benefit payments, 2016	598
Expected benefit payments, 2017	618
Expected benefit payments, 2018-2022	$ 3,315

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Pension Plans And Postretirement Benefits (Effect Of One-Percentage-Point Change In Assumed Health-Care Cost Trend Rates) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
One-Percentage-Point Increase, Effect on total of service and interest cost	$ 475
One-Percentage-Point Increase, Effect on postretirement benefit obligation	7,756
One-Percentage-Point Decrease, Effect on total of service and interest cost	(401)
One-Percentage-Point Decrease, Effect on postretirement benefit obligation	$ (6,456)

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Pension Plans And Postretirement Benefits (Summary of Contribution to Multiemployer Plans) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Multiemployer Plans [Line Items]
Contributions	$ 24.2	$ 31.4	$ 18.4
Boilermaker-Blacksmith National Pension Trust [Member]
Multiemployer Plans [Line Items]
EIN/PIN	48-6168020/ 001
Pension Protection Act Zone Zone Status	Yellow	Yellow
FIP/RP Status -Pending/Implemented	Yes
Contributions	18.9	25.9	12.4
Surcharge Imposed	No
All Other [Member]
Multiemployer Plans [Line Items]
Contributions	$ 5.3	$ 5.5	$ 6.0

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Pension Plans And Postretirement Benefits (Additional Information) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in accumulated other comprehensive income due to actuarial losses-before taxes	$ (1,957)	$ (3,258)
Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase (decrease) in accumulated other comprehensive income due to actuarial losses-before taxes	$ 1,302	$ 1,616

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Income Taxes (Valuation Allowance For Deferred Tax Assets) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Valuation Allowance [Line Items]
Beginning Balance	$ (9,354)	$ (2,205)	$ (28,701)
Charges To Costs and Expenses	(10,625)	(7,149)	6,904
Charged To Other Accounts (In thousands)
Effect Of Spin-Off			19,592	[1]
Ending Balance	$ (19,979)	$ (9,354)	$ (2,205)

[1] (1) Effect of spin-off includes state tax valuation allowances distributed to MII in the spin-off.

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Segment Reporting

12 Months Ended

Dec. 31, 2012

Segment Reporting

NOTE 17 – SEGMENT REPORTING

Our reportable segments are Power Generation, Nuclear Operations, Technical Services and Nuclear Energy, as described in Note 1. The operations of our segments are managed separately and each has unique technology, services and customer class.

We account for intersegment sales at prices that we generally establish by reference to similar transactions with unaffiliated customers. Reportable segments are measured based on operating income exclusive of general corporate expenses, contract and insurance claims provisions, legal expenses and gains (losses) on sales of corporate assets. As described in Note 1, we have changed our accounting method regarding recognition of actuarial gains and losses. We have excluded from reportable segments the fourth quarter recognition of actuarial gains and losses as described in Note 1. Accordingly, we have adjusted previously disclosed segment information for this change in accounting.

1. Information about Operations in our Different Industry Segments:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
REVENUES (1):
Power Generation	$	1,785,959		$	1,541,509		$	1,424,574
Nuclear Operations		1,098,031			1,043,185			995,969
Technical Services		107,851			119,711			90,147
Nuclear Energy		325,953			321,406			196,282
Adjustments and Eliminations		(26,435	)		(73,771	)		(18,161	)
	$	3,291,359		$	2,952,040		$	2,688,811

⁽¹⁾  Segment revenues are net of the following intersegment transfers and other adjustments:

Power Generation Transfers	$	7,932	$	53,852	$	5,092
Nuclear Operations Transfers		6,015		5,860		4,423
Technical Services Transfers		3,496		2,155		2,438
Nuclear Energy Transfers		8,992		11,904		6,208
	$	26,435	$	73,771	$	18,161

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
OPERATING INCOME:
Power Generation	$	183,387		$	183,984		$	169,113
Nuclear Operations		226,269			194,438			168,636
Technical Services		59,655			69,915			47,122
Nuclear Energy		(62,879	)		(116,887	)		(26,442	)
	$	406,432		$	331,450		$	358,429
Unallocated Corporate(1)		(27,953	)		(20,361	)		(18,029	)
Mark to Market Adjustment		(31,890	)		(215,418	)		(91,545	)
Total Operating Income(2)	$	346,589		$	95,671		$	248,855
Other Income (Expense):
Interest income		1,491			1,342			1,187
Interest expense		(3,735	)		(4,543	)		(12,938	)
Other income (expense)—net		(24,927	)		2,028			(16,896	)
Total Other Expense		(27,171	)		(1,173	)		(28,647	)
Income before Provision for Income Taxes	$	319,418		$	94,498		$	220,208

⁽¹⁾       Unallocated corporate includes general corporate overhead not allocated to segments

⁽²⁾       Included in operating income is the following:

(Gains) Losses on Asset Disposals – Net:
Power Generation	$	3,276		$	(3,456	)	$	39
Nuclear Operations		(339	)		—			—
Technical Services		(1,517	)		—			61
Nuclear Energy		(1	)		96			(62	)
Unallocated Corporate		—			273			—
	$	1,419		$	(3,087	)	$	38
Equity in Income of Investees:
Power Generation	$	17,402		$	25,778		$	30,788
Nuclear Operations		—			—			—
Technical Services		49,621			52,877			43,294
Nuclear Energy		(314	)		—			—
	$	66,709		$	78,655		$	74,082

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
SEGMENT ASSETS:
Power Generation	$	1,059,824	$	1,325,959	$	1,082,801
Nuclear Operations		708,607		679,818		639,090
Technical Services		125,494		123,717		85,509
Nuclear Energy		401,233		347,158		339,457
Total Segment Assets		2,295,158		2,476,652		2,146,857
Corporate Assets		545,197		312,459		353,653
Total Assets	$	2,840,355	$	2,789,111	$	2,500,510
CAPITAL EXPENDITURES:
Power Generation	$	24,592	$	15,788	$	13,627
Nuclear Operations		44,810		32,082		24,718
Technical Services		—		—		15
Nuclear Energy		8,435		7,257		4,480
Segment Capital Expenditures		77,837		55,127		42,840
Corporate Capital Expenditures		8,798		8,747		20,809
Total Capital Expenditures	$	86,635	$	63,874	$	63,649
DEPRECIATION AND AMORTIZATION:
Power Generation	$	19,126	$	17,264	$	18,564
Nuclear Operations		32,013		38,169		36,955
Technical Services		244		262		263
Nuclear Energy		6,202		5,346		4,988
Segment Depreciation and Amortization		57,585		61,041		60,770
Corporate Depreciation and Amortization		12,112		11,962		10,863
Total Depreciation and Amortization	$	69,697	$	73,003	$	71,633
INVESTMENT IN UNCONSOLIDATED AFFILIATES:
Power Generation	$	139,399	$	124,686	$	95,527
Nuclear Operations		—		—		—
Technical Services		46,928		38,882		5,284
Nuclear Energy		27		—		—
Total Investment in Unconsolidated Affiliates	$	186,354	$	163,568	$	100,811

2. Information about our Product and Service Lines:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
REVENUES:
Power Generation:
New Build Environmental Equipment	$	446,514		$	235,750		$	277,531
New Build Steam Generation Systems		511,201			416,779			386,356
Aftermarket Services		841,571			894,677			765,573
Eliminations/Other		(13,327	)		(5,697	)		(4,886	)
		1,785,959			1,541,509			1,424,574
Nuclear Operations:
Nuclear Component Program		1,086,081			1,025,838			986,952
Commercial Operations		5,908			11,674			4,449
Eliminations/Other		6,042			5,673			4,568
		1,098,031			1,043,185			995,969
Technical Services:
Commercial Operations		20,819			29,708			28,862
Nuclear Environmental Services		78,228			76,267			48,351
Management & Operation Contracts of U.S. Government Facilities		8,804			13,736			12,934
Eliminations/Other		—			—			—
		107,851			119,711			90,147
Nuclear Energy:
Nuclear Services		158,365			151,118			119,244
Nuclear Equipment		134,011			122,789			72,336
Nuclear Projects		33,319			45,539			4,700
Eliminations/Other		258			1,960			2
		325,953			321,406			196,282
Eliminations		(26,435	)		(73,771	)		(18,161	)
	$	3,291,359		$	2,952,040		$	2,688,811

3. Information about our Operations in Different Geographic Areas:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
REVENUES(1):
United States	$	2,615,387	$	2,340,299	$	2,133,924
Canada		288,246		238,663		252,089
Sweden		101,688		94,337		48,632
China		45,830		48,153		48,285
Germany		34,364		8,222		3,464
Argentina		23,529		21,016		4,374
Denmark		18,504		12,310		15,040
Finland		17,143		20,723		4,040
Korea		14,461		6,272		9,114
India		13,306		8,891		16,277
Chile		11,582		6,811		2,870
Norway		9,939		29,844		33,353
Italy		8,477		6,516		11,361
Saudi Arabia		7,973		3,307		1,689
Indonesia		7,828		4,642		6,048
United Kingdom		6,653		6,150		6,791
Japan		6,497		8,716		8,797
Bulgaria		2,620		14,149		2,144
Brazil		2,585		4,671		2,957
France		2,384		3,433		5,373
Ireland		2,189		14,769		26,574
Other Countries		50,174		50,146		45,615
	$	3,291,359	$	2,952,040	$	2,688,811
(1)       We allocate geographic revenues based on the location of the customer’s operations.
NET PROPERTY, PLANT AND EQUIPMENT:
United States	$	363,447	$	348,498	$	345,848
Canada		45,402		41,868		41,959
United Kingdom		9,714		9,758		10,401
Denmark		8,565		8,813		8,395
Mexico		8,302		7,024		6,299
Other Countries		11,591		6,330		5,410
	$	447,021	$	422,291	$	418,312

4. Information about our Major Customers:

In the years ended December 31, 2012, 2011 and 2010, the U.S. Government accounted for approximately 34%, 38% and 39%, respectively, of our total revenues. Substantially, these revenues are included in our Nuclear Operations and Technical Services segments.

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Basis of Presentation and Significant Accounting Policies (Asset Retirement Obligations) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Asset Retirement Obligations [Line Items]
Balance at beginning of period	$ 35,885	$ 32,657	$ 29,491
Costs incurred		(2,265)
Additions/Adjustments	3,422	2,935
Accretion	3,059	2,558	3,166
Balance at end of period	$ 42,366	$ 35,885	$ 32,657

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Quarterly Financial Data (Tables)

12 Months Ended

Dec. 31, 2012

Selected Quarterly Financial Information

The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 2012 and 2011:

	Year Ended December 31, 2012 Quarter Ended
	March  31, 2012		June  30, 2012		Sept. 30, 2012		Dec. 31, 2012
	(In thousands, except per share amounts)
Revenues	$	765,892	$	852,585	$	807,586	$	865,296
Operating income (1)	$	86,420	$	110,077	$	84,399	$	65,693
Equity in income of investees	$	17,357	$	16,687	$	14,546	$	18,119
Net income attributable to The Babcock & Wilcox Company	$	59,950	$	77,231	$	51,443	$	39,071
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	0.51	$	0.65	$	0.43	$	0.33
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	0.50	$	0.65	$	0.43	$	0.33
(1)       Includes equity in income of investees.

	Year Ended December 31, 2011 Quarter Ended
	March  31, 2011		June  30, 2011		Sept. 30, 2011		Dec. 31, 2011
	(In thousands, except per share amounts)
Revenues	$	691,277	$	752,352	$	707,622	$	800,789
Operating income (loss) (1)	$	41,394	$	82,809	$	74,912	$	(103,444	)
Equity in income of investees	$	15,361	$	18,381	$	22,782	$	22,131
Net income (loss) attributable to The Babcock & Wilcox Company	$	25,921	$	58,665	$	56,742	$	(63,009	)
Earnings per common share:
Basic:
Net income (loss) attributable to The Babcock & Wilcox Company	$	0.22	$	0.50	$	0.48	$	(0.53	)
Diluted:
Net income (loss) attributable to The Babcock & Wilcox Company	$	0.22	$	0.50	$	0.48	$	(0.53	)
(1)       Includes equity in income of investees.

Schedule of Adjustments on Previously Reported Quarterly Results

The impact of these adjustments on previously reported quarterly results is summarized below (in thousands, except per share amounts):

Increase (Decrease) from	First Quarter				Second Quarter				Third Quarter				Fourth Quarter
Previously Reported Amounts	2012		2011		2012		2011		2012		2011		2012			2011
Operating income	$	20,709	$	19,493	$	20,718	$	19,552	$	17,092	$	17,361	$	(12,486	)	$	(196,703	)
Net income attributable to The Babcock & Wilcox Company	$	13,206	$	12,411	$	13,207	$	12,456	$	10,922	$	11,079	$	(8,692	)	$	(127,281	)
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	0.11	$	0.10	$	0.11	$	0.11	$	0.09	$	0.09	$	(0.07	)	$	(1.07	)
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	0.11	$	0.11	$	0.11	$	0.11	$	0.09	$	0.09	$	(0.07	)	$	(1.07	)

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Pension Plans And Postretirement Benefits (Obligations And Funded Status) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at the end of period	$ 2,165,018	$ 1,951,408
Accumulated postretirement benefit obligation	(71,208)	(80,663)
Pension liability	(579,165)	(586,045)
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of period	2,687,007	2,479,783
Service cost	46,828	43,495	39,176
Interest cost	122,605	134,927	142,092
Plan participants' contributions	300	318
Curtailments	(94,642)
Amendments	2,996	2,055
Settlements	(57,430)	(13,625)
Actuarial loss (gain)	198,935	181,517
Foreign currency exchange rate changes	6,793	(5,633)
Benefits paid	(133,402)	(135,830)
Benefit obligation at end of period	2,779,990	2,687,007	2,479,783
Fair value of plan assets at beginning of period	1,917,850	1,782,048
Actual return on plan assets	207,728	115,787
Plan participants' contributions	300	318
Company contributions	187,284	174,639
Settlements	(57,430)	(13,625)
Foreign currency exchange rate changes	5,364	(5,487)
Benefits paid	(133,402)	(135,830)
Fair value of plan assets at the end of period	2,127,694	1,917,850	1,782,048
Funded status	(652,296)	(769,157)
Accrued employee benefits	(75,119)	(185,832)
Pension liability	(577,177)	(583,337)
Prepaid pension		12
Accrued benefit liability, net	(652,296)	(769,157)
Prior service cost (credit)	18,327	19,949
Plans with accumulated benefit obligation in excess of plan assets, Projected benefit obligation	2,779,990	2,686,796
Plans with accumulated benefit obligation in excess of plan assets, Accumulated benefit obligation	2,723,930	2,515,868
Plans with accumulated benefit obligation in excess of plan assets, Fair value of plan assets	2,127,694	1,917,626
Plans with plan assets in excess of accumulated benefit obligation, Projected benefit obligation		211
Plans with plan assets in excess of accumulated benefit obligation, Accumulated benefit obligation		211
Plans with plan assets in excess of accumulated benefit obligation, Fair value of plan assets		224
Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of period	122,460	125,692
Service cost	1,138	1,143	1,069
Interest cost	5,124	5,805	7,284
Plan participants' contributions	115	116
Amendments	(1,302)	(1,351)
Actuarial loss (gain)	(2,153)	1,491
Foreign currency exchange rate changes	220	(211)
Benefits paid	(9,346)	(10,225)
Benefit obligation at end of period	116,256	122,460	125,692
Fair value of plan assets at beginning of period	33,558	33,389
Actual return on plan assets	2,233	723
Plan participants' contributions	115	116
Company contributions	10,764	9,555
Benefits paid	(9,346)	(10,225)
Fair value of plan assets at the end of period	37,324	33,558	33,389
Funded status	(78,932)	(88,902)
Accrued employee benefits	(7,724)	(8,239)
Accumulated postretirement benefit obligation	(71,208)	(80,663)
Accrued benefit liability, net	(78,932)	(88,902)
Prior service cost (credit)	(2,523)	(1,360)
Plans with accumulated benefit obligation in excess of plan assets, Accumulated benefit obligation	116,256	122,460
Plans with accumulated benefit obligation in excess of plan assets, Fair value of plan assets	$ 37,324	$ 33,558

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Commitments and Contingencies (Narrative) (Detail) (USD $)	12 Months Ended						1 Months Ended		12 Months Ended			1 Months Ended				12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Feb. 14, 2012	Oct. 31, 2011 Nuclear Fuel Services, Inc. [Member] Plaintiff	Jun. 30, 2011 Nuclear Fuel Services, Inc. [Member] Plaintiff	Jun. 30, 2012 Apollo And Parks Township [Member] Claim	Dec. 31, 2009 Apollo And Parks Township [Member]	Dec. 31, 2012 Apollo And Parks Township [Member] Cases Facility	Dec. 31, 2008 Apollo And Parks Township [Member]	Dec. 31, 1998 Apollo And Parks Township [Member]	Dec. 31, 2009 Apollo And Parks Township [Member] Personal Injury And Wrongful Death Claims [Member] Claim	Dec. 31, 2009 Apollo And Parks Township [Member] Property Damage Claims [Member] Claim	Dec. 31, 2012 Apollo And Parks Township [Member] 2008 Settlement [Member]	Dec. 31, 2012 Apollo And Parks Township [Member] 2009 Settlement [Member]	Dec. 31, 2012 Environmental Matters [Member]	Dec. 31, 2012 Enviornmental Matters [Member]	Dec. 31, 2010 Enviornmental Matters [Member]	Dec. 31, 2011 Enviornmental Matters [Member]
Contingencies And Commitments [Line Items]
Number of claimants					140	18	85
Number of additional claims							10
Number of facilities									2
Number of cases consolidated for most non-dispositive pre-trial matters									11
Aggregate settlement amount for claims								$ 52,500,000		$ 27,500,000	$ 8,000,000
Number of claims settled												250	125
Percentage of ARCO's recovery amounts assigned to company									58.33%
Interest accrued on settlement														8,800,000	6,200,000
Interest rate on settlement				6.00%
Appeal bond required as a percentage of total judgment				120.00%
Liquidated contingency sum				5,000,000
Financial assurance to pay expected cost of decommissioning																43,500,000
Pretax charge to comply U.S. federal, state and local environmental control and protection regulations																15,300,000
Capital expenditure to comply environmental regulations																	3,200,000
Environmental reserves																	49,600,000		47,300,000
Environmental reserves included in current liabilities																	3,100,000		3,200,000
Gain due to decrease in accrual																		8,700,000
Total rental expense	$ 12.1	$ 11.1	$ 10.5

XML

Commitments And Contingencies (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Future Minimum Payments for Operating Leases

Fiscal Year Ending December 31,	Amount
2013	$	10,314
2014	$	9,168
2015	$	10,751
2016	$	4,761
2017	$	4,207
Thereafter	$	4,734

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Basis of Presentation and Significant Accounting Policies (Property, Plant and Equipment) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	$ 1,099,040	$ 1,017,422
Less accumulated depreciation	652,019	595,131
Net Property, Plant And Equipment	447,021	422,291	418,312
Land [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	11,875	11,656
Buildings [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	241,281	224,661
Machinery and equipment [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	776,678	710,666
Property under construction [Member]
Property, Plant and Equipment [Line Items]
Property plant and equipment gross	$ 69,206	$ 70,439

XML

Income Taxes (Components Of Deferred Tax Assets And Liabilities) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Components Of Deferred Tax Assets And Liabilities [Line Items]
Pension liability	$ 201,229	$ 216,248
Accrued warranty expense	26,695	33,412
Accrued vacation pay	13,312	13,269
Accrued liabilities for self-insurance (including postretirement health care benefits)	35,374	41,243
Accrued liabilities for executive and employee incentive compensation	39,483	29,539
Environmental and products liabilities	8,024	7,711
Investments in joint ventures and affiliated companies	16,993	3,704
Long-term contracts	29,807	22,871
Net operating loss carryforward	15,787	22,380
State tax net operating loss carryforward	21,757	22,734
Foreign tax credit carryforward	808	18,292
Other	7,722	8,273
Total deferred tax assets	416,991	439,676
Valuation allowance for deferred tax assets	(19,979)	(9,354)	(2,205)	(28,701)
Deferred tax assets	397,012	430,322
Property, plant and equipment	39,016	31,874
Investments in joint ventures and affiliated companies	1,064	791
Long-term contracts	30,571	27,681
Intangibles	24,756	26,365
Other	9,580	8,080
Total deferred tax liabilities	104,987	94,791
Net deferred tax assets	$ 292,025	$ 335,531

XML

Segment Reporting (Schedule of Segment Reporting Information) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Segment Reporting Information [Line Items]
Total Assets	$ 2,840,355	$ 2,789,111	$ 2,500,510
Total Capital Expenditures	86,635	63,874	63,649
Total Depreciation and Amortization	69,697	73,003	71,633
Total Investment in Unconsolidated Affiliates	186,354	163,568	100,811
Power Generation [Member]
Segment Reporting Information [Line Items]
Total Assets	1,059,824	1,325,959	1,082,801
Total Capital Expenditures	24,592	15,788	13,627
Total Depreciation and Amortization	19,126	17,264	18,564
Total Investment in Unconsolidated Affiliates	139,399	124,686	95,527
Nuclear Operations [Member]
Segment Reporting Information [Line Items]
Total Assets	708,607	679,818	639,090
Total Capital Expenditures	44,810	32,082	24,718
Total Depreciation and Amortization	32,013	38,169	36,955
Total Investment in Unconsolidated Affiliates
Technical Services [Member]
Segment Reporting Information [Line Items]
Total Assets	125,494	123,717	85,509
Total Capital Expenditures			15
Total Depreciation and Amortization	244	262	263
Total Investment in Unconsolidated Affiliates	46,928	38,882	5,284
Nuclear Energy [Member]
Segment Reporting Information [Line Items]
Total Assets	401,233	347,158	339,457
Total Capital Expenditures	8,435	7,257	4,480
Total Depreciation and Amortization	6,202	5,346	4,988
Total Investment in Unconsolidated Affiliates	27
Segments [Member]
Segment Reporting Information [Line Items]
Total Assets	2,295,158	2,476,652	2,146,857
Total Capital Expenditures	77,837	55,127	42,840
Total Depreciation and Amortization	57,585	61,041	60,770
Corporate [Member]
Segment Reporting Information [Line Items]
Total Assets	545,197	312,459	353,653
Total Capital Expenditures	8,798	8,747	20,809
Total Depreciation and Amortization	$ 12,112	$ 11,962	$ 10,863

XML

Equity Method Investments (Summary Of Combined Balance Sheet Information) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Schedule of Variable Interest Entities for Loans to Commercial Borrowers [Line Items]
Current assets	$ 835,997	$ 855,962
Noncurrent assets	271,233	211,920
Total Assets	1,107,230	1,067,882
Current liabilities	616,786	594,883
Noncurrent liabilities	89,285	112,936
Owners' equity	401,159	360,063
Total Liabilities and Owners' Equity	$ 1,107,230	$ 1,067,882

XML

Basis of Presentation and Significant Accounting Policies (Retainages on Contracts) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Basis Of Presentation And Significant Accounting Policies [Line Items]
Retainages expected to be collected within one year	$ 85,776	$ 60,158
Retainages expected to be collected after one year	28,661	14,526
Total retainages	$ 114,437	$ 74,684

XML

Basis Of Presentation And Significant Accounting Policies

12 Months Ended

Dec. 31, 2012

Basis Of Presentation And Significant Accounting Policies

NOTE 1 – BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING POLICIES

We have presented the consolidated and combined financial statements of The Babcock & Wilcox Company (“B&W”) in U.S. Dollars in accordance with accounting principles generally accepted in the United States (“GAAP”). On and prior to July 30, 2010, our financial position, operating results and cash flows consisted of The Babcock & Wilcox Operations of McDermott International, Inc., (“BWO”), which represented a combined reporting entity comprised of the assets and liabilities involved in managing and operating what was previously the Power Generation Systems and Government Operations segments of McDermott International, Inc., a Panamanian corporation (“MII”). In addition, two captive insurance companies were combined and contributed to B&W in conjunction with the spin-off of B&W by MII. On our consolidated and combined statements of income and cash flows, the twelve months ended December 31, 2010 include the combined results of operations for seven months of BWO and five months of the consolidated results of B&W.

B&W was a wholly owned subsidiary of MII until July 30, 2010 when MII distributed 100% of our outstanding common stock to the MII shareholders. On July 2, 2010, MII’s Board of Directors approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of MII common stock. The distribution of B&W common stock was made on July 30, 2010, and consisted of one share of B&W common stock for every two shares of MII common stock to holders of MII common stock as of 5:00 p.m. New York City time on the record date, July 9, 2010. Cash was paid in lieu of any fractional shares of B&W common stock. B&W became a separate publicly traded company, and MII did not retain any ownership interest in B&W. A registration statement on Form 10 describing the spin-off was filed by B&W with the Securities and Exchange Commission and was declared effective on July 8, 2010 (as amended through the time of such effectiveness).

We use the equity method to account for investments in entities that we do not control, but over which we have the ability to exercise significant influence. We generally refer to these entities as “joint ventures.” We have eliminated all intercompany transactions and accounts.

Certain corporate and general and administrative expenses incurred before the spin-off, including those related to executive management, investor relations, tax, accounting, legal and treasury services, and certain employee benefits, have been allocated based on a level of effort calculation. Our management believes such allocations are reasonable. However, the associated expenses reflected in the accompanying consolidated and combined statements of income may not be indicative of the actual expenses that would have been incurred had the combined businesses been operating as an independent public company for all periods presented. Since the spin-off from MII, B&W has been performing these functions using internal resources or services provided by third parties, certain of which were provided by MII during a transitional period pursuant to a transition services agreement. We have terminated most of the services under the transition services agreement.

Unless the context otherwise indicates, “we,” “us” and “our” mean B&W and its consolidated and combined subsidiaries.

Pension Accounting Change

In the fourth quarter of 2012, we elected to change our accounting method for recognizing actuarial gains and losses for our pension and other postretirement benefit plans. Historically, these gains and losses were recognized as a component of accumulated other comprehensive income on our consolidated balance sheets and we amortized these actuarial gains and losses into earnings over the average remaining service period for our Canadian plans to the extent such gains and losses exceeded a corridor and for our domestic plans we used an amortization method over the average remaining service period without the use of a corridor. Under our new accounting method, we will immediately recognize actuarial gains and losses into earnings in the fourth quarter each year as a component of net periodic benefit cost. This new accounting method results in actuarial gains and losses being recognized faster than our previous amortization method. We believe the new accounting method is preferable as this accelerated method recognizes the effects of plan investment performance, interest rate movements and changes in other actuarial assumptions as a component of earnings in the period they occur. This change has been reported through retrospective application of the new accounting method to all periods presented. See Note 6 for a further discussion of our pension and postretirement benefits and Note 20 for disclosures relating to the effect of this change in our accounting method.

Business Segments

We operate in four business segments: Power Generation, Nuclear Operations, Technical Services and Nuclear Energy. For financial information about our segments, see Note 17 to our consolidated and combined financial statements included in this report.

Our segments are further described as follows:

• Our Power Generation segment supplies boilers fired with fossil fuels, such as coal, oil and natural gas, or renewable fuels such as biomass and municipal solid waste. In addition, we supply environmental equipment and components and related services to customers in different regions around the world. This segment owns or leases manufacturing facilities in the U.S., Canada, Denmark, Germany, Mexico, China and Scotland. We design, engineer, manufacture, supply, construct and service large utility and industrial power generation systems, including boilers used to generate steam in electric power plants, pulp and paper making, chemical and process applications and other industrial uses. We also provide the same compliment of services for our renewable portfolio of boiler technology, which includes biomass fired, waste-to-energy and concentrated solar energy for steam generating solutions. In addition, this segment is a technological leader in providing cost-effective and efficient air pollution control solutions and material handling systems. We have successfully developed advanced technologies to control nitrogen oxides, sulfur dioxide, fine particulate, mercury, acid gases and other hazardous air emissions. In addition, our Power Generation segment offers a variety of construction services for the entire balance of plant, from large steam generation or environmental equipment projects, to cogeneration and combined cycle installations. This segment also offers a full suite of aftermarket services. Our Power Generation segment’s full-scope boiler, environmental and auxiliary equipment retrofits, upgrades and services improve plant performance and efficiency and extend the life of vital steam generating assets.

• Our Nuclear Operations segment manufactures naval nuclear reactors for the U.S. Department of Energy (“DOE”)/National Nuclear Security Administration’s (“NNSA”) Naval Nuclear Propulsion Program, which in turn supplies them to the U.S. Navy for use in submarines and aircraft carriers. Through this segment, we own and operate manufacturing facilities located in Lynchburg, Virginia; Mount Vernon, Indiana; Euclid, Ohio; Barberton, Ohio; and Erwin, Tennessee. The Barberton, Ohio and Mount Vernon, Indiana locations specialize in the design and manufacture of heavy components. These two locations are N-Stamp accredited by the American Society of Mechanical Engineers (“ASME”), making them two of only a few North American suppliers of large, heavy-walled nuclear components and vessels. The Euclid, Ohio facility, which is also ASME N-Stamp certified, fabricates electro-mechanical equipment for the U.S. Government, and performs design, manufacturing, inspection, assembly and testing activities. The Lynchburg, Virginia operations fabricate fuel-bearing precision components that range in weight from a few grams to hundreds of tons. In-house capabilities also include wet chemistry uranium processing, advanced heat treatment to optimize component material properties and a controlled, clean-room environment with the capacity to assemble railcar-size components. Fuel for the naval nuclear reactors is provided by Nuclear Fuel Services, Inc. (“NFS”), one of our wholly owned subsidiaries. Located in Erwin, Tennessee, NFS also converts cold war-era government stockpiles of highly enriched uranium into material suitable for further processing into commercial nuclear reactor fuel.

• Our Technical Services segment provides various services to the U.S. Government, including uranium processing, environmental site restoration services and management and operating services for various U.S. Government-owned facilities. These services are provided to the DOE, including the NNSA, the Office of Nuclear Energy, the Office of Science, the Department of Defense and the Office of Environmental Management, and through this segment we deliver products and management solutions to nuclear operations and high-consequence manufacturing facilities. A significant portion of this segment’s operations are conducted through joint ventures.

• Our Nuclear Energy segment supplies commercial nuclear steam generators and components to nuclear utility customers. In addition, this segment is actively designing the modular and scalable B&W mPower^TM reactor. B&W has supplied the nuclear industry with more than 1,300 large, heavy components worldwide. With manufacturing operations in the U.S. and Canada, this segment is the only heavy nuclear component, N-Stamp certified manufacturer in North America. Our Nuclear Energy segment fabricates pressure vessels, reactors, steam generators, heat exchangers and other auxiliary equipment. This segment also provides specialized engineering services that include structural component design, 3-D thermal-hydraulic engineering analysis, weld and robotic process development and metallurgy and materials engineering. Our Nuclear Energy segment also provides power plant construction and management and maintenance services. In addition, this segment offers services for nuclear steam generators and balance of plant equipment, as well as nondestructive examination and tooling/repair solutions for other plant systems and components.

The consolidated results of operations, financial position and cash flows for the year ended December 31, 2012 are not necessarily indicative of the results that may be expected for the year ending December 31, 2013.

Use of Estimates

We use estimates and assumptions to prepare our financial statements in conformity with GAAP. Some of our more significant estimates include our estimate of costs to complete long-term construction contracts and estimates we make in selecting assumptions related to the valuations of our pension and postretirement plans, including the selection of our discount rates and expected rates of return on our pension plan assets. These estimates and assumptions affect the amounts we report in our financial statements and accompanying notes. Our actual results could differ from these estimates. Variances could result in a material effect on our financial condition and results of operations in future periods.

Earnings Per Share

We have computed earnings per common share on the basis of the weighted average number of common shares, and, where dilutive, common share equivalents, outstanding during the indicated periods. On July 30, 2010, 116,225,732 shares of our common stock were distributed to MII shareholders to complete our spin-off from MII. For comparative purposes, and to provide a more meaningful calculation of weighted average shares, we have assumed this amount to be outstanding as of the beginning of each period presented prior to our spin-off in our calculation of basic weighted average shares. In addition, for our dilutive weighted average share calculations, we have assumed the dilutive securities outstanding at July 30, 2010 were also outstanding at each of the periods presented prior to our spin-off.

Investments

Our investments, primarily U.S. Government obligations and other highly liquid money market instruments, are classified as available-for-sale and are carried at fair value, with the unrealized gains and losses, net of tax, reported as a component of accumulated other comprehensive income. We classify investments available for current operations in the consolidated balance sheets as current assets, while we classify investments held for long-term purposes as noncurrent assets. We adjust the amortized cost of debt securities for amortization of premiums and accretion of discounts to maturity. That amortization is included in interest income. We include realized gains and losses on our investments in other income (expense) – net. The cost of securities sold is based on the specific identification method. We include interest on securities in interest income.

Foreign Currency Translation

We translate assets and liabilities of our foreign operations into U.S. dollars at current exchange rates, and we translate income statement items at average exchange rates for the periods presented. We record adjustments resulting from the translation of foreign currency financial statements as a component of accumulated other comprehensive income. We report foreign currency transaction gains and losses in income. We have included in other income (expense)—net transaction losses of $0.6 million, $1.9 million and $6.5 million for the years ended December 31, 2012, 2011 and 2010, respectively.

Contracts and Revenue Recognition

We generally recognize contract revenues and related costs on a percentage-of-completion method for individual contracts or combinations of contracts based on work performed, man hours, or a cost-to-cost method, as applicable to the product or activity involved. We recognize estimated contract revenue and resulting income based on the measurement of the extent of progress completion as a percentage of the total project. Certain costs may be excluded from the cost-to-cost method of measuring progress, such as significant costs for materials and major third party subcontractors, if it appears that such exclusion would result in a more meaningful measurement of actual contract progress and resulting periodic allocation of income. We include revenues and related costs so recorded, plus accumulated contract costs that exceed amounts invoiced to customers under the terms of the contracts, in contracts in progress. We include in advance billings on contracts billings that exceed accumulated contract costs and revenues and costs recognized under the percentage-of-completion method. Most long-term contracts contain provisions for progress payments. Our unbilled receivables do not contain an allowance for credit losses as we expect to invoice customers and collect all amounts for unbilled revenues. We review contract price and cost estimates periodically as the work progresses and reflect adjustments proportionate to the percentage-of-completion in income in the period when those estimates are revised. For all contracts, if a current estimate of total contract cost indicates a loss on a contract, the projected loss is recognized in full when determined.

For contracts as to which we are unable to estimate the final profitability except to assure that no loss will ultimately be incurred, we recognize equal amounts of revenue and cost until the final results can be estimated more precisely. For these deferred profit recognition contracts, we recognize revenue and cost equally and only recognize gross margin when probable and reasonably estimable, which we generally determine to be when the contract is approximately 70% complete. We treat long-term construction contracts that contain such a level of risk and uncertainty that estimation of the final outcome is impractical, except to assure that no loss will be incurred, as deferred profit recognition contracts.

Our policy is to account for fixed-price contracts under the completed-contract method if we believe that we are unable to reasonably forecast cost to complete at start-up. Under the completed-contract method, income is recognized only when a contract is completed or substantially complete.

For the majority of parts orders and certain aftermarket services activities, we recognize revenues as goods are delivered and work is performed.

Variations from estimated contract performance could result in material adjustments to operating results for any fiscal quarter or year. We include claims for extra work or changes in scope of work to the extent of costs incurred in contract revenues when we believe collection is probable.

In the year ended December 31, 2012, we recorded a contract loss totaling approximately $16.9 million, net of claims, based on our estimate of costs to complete a project in our Power Generation segment. In the year ended December 31, 2011, we recorded additional costs totaling approximately $61.8 million ($50.7 million in our Nuclear Energy segment and $11.1 in our Nuclear Operations segment) to complete certain projects attributable to changes in estimate due to productivity and scheduling issues. In May 2012, we entered into an agreement with the customer of the Nuclear Energy project to settle contract claims resulting in recognition of revenues totaling approximately $18.4 million in 2012. These projects are now complete.

Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and the applicable customer asserts a claim under these provisions. These contracts define the conditions and timing under which our customers may make claims against us for liquidated damages. In the majority of cases in which we have had potential exposure for liquidated damages, such damages ultimately were determined not to be caused by our actions or were not otherwise asserted by our customers. Accordingly, we do not accrue liabilities for liquidated damages unless probable and estimable. As of December 31, 2012, we had not accrued for approximately $6.0 million of potential liquidated damages that are not currently due under the particular contract but which we believe could be asserted based upon our current expectations of the time to complete a certain project in our Power Generation segment. We do not believe any of these potential liquidated damages are probable of being assessed due primarily to their relationship to unforeseen worksite conditions that we believe are the responsibility of our customer. We are in active discussions with our customer on the issues giving rise to delays in this project, and we believe we will be successful in obtaining schedule extensions that should resolve the potential for liquidated damages liability. However, we may not achieve relief on some or all of the issues.

The following represent the components of our contracts in progress and advance billings on contracts included in our consolidated balance sheets:

	December 31,
	2012			2011
	(In thousands)
Included in Contracts in Progress:
Costs incurred less costs of revenue recognized	$	135,972		$	135,513
Revenues recognized less billings to customers		180,546			179,773
Contracts In Progress	$	316,518		$	315,286
Included In Advance Billings on Contracts:
Billings to customers less revenues recognized	$	541,983		$	492,106
Costs incurred less costs of revenue recognized		(69,696	)		(53,353	)
Advance Billings on Contracts	$	472,287		$	438,753

The following amounts represent retainages on contracts:

	December 31,
	2012		2011
	(In thousands)
Retainages expected to be collected within one year	$	85,776	$	60,158
Retainages expected to be collected after one year		28,661		14,526
Total retainages	$	114,437	$	74,684

We have included in accounts receivable – trade retainages expected to be collected in 2013. Retainages expected to be collected after one year are included in other assets. Of the long-term retainages at December 31, 2012, we anticipate collecting $23.1 million in 2014, $2.9 million in 2015 and $2.7 million in 2016.

Comprehensive Income

The components of accumulated other comprehensive income included in stockholders’ equity are as follows:

	December 31,
	2012			2011
	(In thousands)
Currency translation adjustments	$	40,899		$	36,626
Net unrealized gain on investments		597			201
Net unrealized gain on derivative financial instruments		2,103			2,717
Unrecognized prior service cost on benefit obligations		(10,871	)		(12,718	)
Accumulated other comprehensive income	$	32,728		$	26,826

Warranty Expense

We accrue estimated expense, included in cost of operations on our consolidated and combined statements of income, to satisfy contractual warranty requirements when we recognize the associated revenue on the related contracts. In addition, we make specific provisions or reductions where we expect the actual warranty costs to significantly differ from the accrued estimates. Such changes could have a material effect on our consolidated financial condition, results of operations and cash flows.

The following summarizes the changes in the carrying amount of accrued warranty expense:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	97,209		$	109,588		$	115,055
Additions		20,972			21,267			31,660
Expirations and other changes		(24,766	)		(14,288	)		(28,032	)
Charges		(10,217	)		(19,035	)		(10,532	)
Translation and other		484			(323	)		1,437
Balance at end of period	$	83,682		$	97,209		$	109,588

Asset Retirement Obligations and Environmental Clean-up Costs

We accrue for future decommissioning of our nuclear facilities that will permit the release of these facilities to unrestricted use at the end of each facility’s life, which is a requirement of our licenses from the U.S. Nuclear Regulatory Commission (the “NRC”). In accordance with the FASB Topic Asset Retirement and Environmental Obligations, we record the fair value of a liability for an asset retirement obligation in the period in which it is incurred. When we initially record such a liability, we capitalize a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of a liability, we will settle the obligation for its recorded amount or incur a gain or loss. This topic applies to environmental liabilities associated with assets that we currently operate and are obligated to remove from service. For environmental liabilities associated with assets that we no longer operate, we have accrued amounts based on the estimated costs of clean-up activities for which we are responsible, net of any cost-sharing arrangements. We adjust the estimated costs as further information develops or circumstances change. An exception to this accounting treatment relates to the work we perform for two facilities for which the U.S. Government is obligated to pay substantially all of the decommissioning costs.

Substantially all of our asset retirement obligations relate to the remediation of our nuclear analytical laboratory and the NFS facility in our Nuclear Operations segment. The following table reflects our asset retirement obligations:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Balance at beginning of period	$	35,885	$	32,657		$	29,491
Costs incurred		—		(2,265	)		—
Additions/Adjustments		3,422		2,935			—
Accretion		3,059		2,558			3,166
Balance at end of period	$	42,366	$	35,885		$	32,657

Research and Development

Our research and development activities are related to the development and improvement of new and existing products and equipment, as well as conceptual and engineering evaluation for translation into practical applications. We charge to research and development cost the costs of research and development unrelated to specific contracts as incurred. Substantially all of these costs are in our Power Generation and Nuclear Energy segments and include costs related to the development of our modular nuclear reactor business, B&W mPower^TM. Contractual arrangements for customer-sponsored research and development can vary on a case-by-case basis and include contracts, cooperative agreements and grants. Research and development activities (including in-kind research and development services described below) totaled $173.9 million, $163.0 million and $102.1 million in the years ended December 31, 2012, 2011 and 2010, respectively, which include amounts paid for by our customers of $53.4 million, $56.6 million and $32.9 million, respectively.

During the years ended December 31, 2012 and 2011, we recognized $17.9 million and $16.6 million, respectively, of non-cash in-kind research and development costs (included above) related to services contributed by our minority partner to Generation mPower LLC (“GmP”), our majority-owned subsidiary formed in 2011 to oversee the program to develop the small modular nuclear power plant based on B&W mPower^TM technology.

In November 2012, our Nuclear Energy segment was selected as the winner of the DOE’s competitively bid Small Modular Reactor (“SMR”) Licensing Technical Support Program, and will receive funding that will support accelerated development of its B&W mPower™ SMR technology.

Income Taxes

Income tax expense for federal, foreign, state and local income taxes are calculated on pre-tax income based on current tax law and include the cumulative effect of any changes in tax rates from those used previously in determining deferred tax assets and liabilities. We record a valuation allowance to reduce our deferred tax assets to the amount that is more likely than not to be realized. We assess deferred taxes and the adequacy of the valuation allowance on a quarterly basis. In the ordinary course of business there is inherent uncertainty in quantifying our income tax positions. We assess our income tax positions and record tax benefits for all years subject to examination based upon management’s evaluation of the facts, circumstances, and information available at the reporting date. For those tax positions where it is more-likely-than-not that a tax benefit will be sustained, we have recorded the largest amount of tax benefit with a greater than 50% likelihood of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. For those income tax positions where it is not more-likely-than-not that a tax benefit will be sustained, no tax benefit has been recognized in the financial statements. We record interest and penalties (net of any applicable tax benefit) related to income taxes as a component of provision for income taxes on our consolidated and combined statements of income.

Inventories

We carry our inventories at the lower of cost or market. We determine cost principally on the first-in, first-out basis, except for certain materials inventories of our Power Generation segment, for which we use the last-in, first-out (“LIFO”) method. We determined the cost of approximately 17% and 19% of our total inventories using the LIFO method at December 31, 2012 and 2011, respectively, and our total LIFO reserve at December 31, 2012 and 2011 was approximately $7.5 million and $7.1 million, respectively. Inventories are summarized below:

	December 31,
	2012		2011
	(In thousands)
Raw Materials and Supplies	$	98,428	$	77,932
Work in Progress		7,956		6,889
Finished Goods		17,834		22,477
Total Inventories	$	124,218	$	107,298

Property, Plant and Equipment

We carry our property, plant and equipment at depreciated cost, less any impairment provisions.

We depreciate our property, plant and equipment using the straight-line method over estimated economic useful lives of eight to 40 years for buildings and two to 28 years for machinery and equipment. Our depreciation expense was $59.4 million, $61.8 million and $61.1 million for the years ended December 31, 2012, 2011 and 2010, respectively.

We expense the costs of maintenance, repairs and renewals that do not materially prolong the useful life of an asset as we incur them.

Property, plant and equipment is stated at cost and is set forth below:

	December 31,
	2012		2011
	(In thousands)
Land	$	11,875	$	11,656
Buildings		241,281		224,661
Machinery and equipment		776,678		710,666
Property under construction		69,206		70,439
		1,099,040		1,017,422
Less accumulated depreciation		652,019		595,131
Net Property, Plant and Equipment	$	447,021	$	422,291

Investments in Unconsolidated Affiliates

We use the equity method of accounting for affiliates in which we are able to exert significant influence. Currently, substantially all of our material investments in affiliates that are not consolidated are recorded using the equity method. Affiliates in which our investment ownership is less than 20% and where we are unable to exert significant influence are carried at cost.

Goodwill

The following summarizes the changes in the carrying amount of goodwill:

	Power Generation		Nuclear Operations			Technical Services		Nuclear Energy		Total
	(In thousands)
Balance at December 31, 2010	$	88,042	$	122,407		$	45,000	$	13,975	$	269,424
Acquisition of Loibl (Note 2)		11,015		—			—		—		11,015
Foreign currency translation adjustments and other		45		(4,304	)		—		—		(4,259	)
Balance at December 31, 2011	$	99,102	$	118,103		$	45,000	$	13,975	$	276,180
Purchase price adjustment for acquisition of Loibl (Note 2)		3,727		—			—		—		3,727
Foreign currency translation adjustments and other		873		—			—		—		873
Balance at December 31, 2012	$	103,702	$	118,103		$	45,000	$	13,975	$	280,780

Intangible Assets

We report our intangible assets in other assets. We amortize those intangible assets with definite lives to operating expense using the straight-line method.

Other assets include the following intangible assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Amortized intangible assets:
Gross cost:
Customer relationships	$	36,644		$	40,051		$	37,167
Acquired backlog		2,979			22,435			19,335
Tradename		11,945			15,169			12,291
Unpatented technology		6,422			6,402			5,902
Patented technology		6,961			6,961			6,625
All other		7,912			7,901			11,935
Total	$	72,863		$	98,919		$	93,255
Accumulated amortization:
Customer relationships	$	(11,173	)	$	(8,618	)	$	(6,026	)
Acquired backlog		(1,457	)		(17,040	)		(12,701	)
Tradename		(6,422	)		(6,509	)		(4,260	)
Unpatented technology		(2,682	)		(2,033	)		(1,407	)
Patented technology		(4,235	)		(3,219	)		(2,096	)
All other		(4,343	)		(3,594	)		(6,296	)
Total	$	(30,312	)	$	(41,013	)	$	(32,786	)
Net amortized intangible assets	$	42,551		$	57,906		$	60,469
Unamortized intangible assets:
NRC category 1 license	$	43,830		$	43,830		$	43,830
Trademarks and trade names		1,305			1,305			1,305
Total unamortized intangible assets	$	45,135		$	45,135		$	45,135

The following summarizes the changes in the carrying amount of intangible assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	103,041		$	105,604		$	103,379
Business acquisitions & adjustments		(1,746	)		9,100			14,280
Amortization expense		(11,010	)		(11,545	)		(11,679	)
Impairment charge		(3,216	)		—			—
Foreign currency translation adjustments and other		617			(118	)		(376	)
Balance at end of period	$	87,686		$	103,041		$	105,604

We recognized an impairment charge totaling $3.2 million in the year ended December 31, 2012 related to the cancellation of an operations and maintenance services contract in our Power Generation segment.

The estimated amortization expense for the next five fiscal years is as follows (in thousands):

Year Ending December 31,	Amount
2013	$	8,023
2014	$	5,494
2015	$	4,292
2016	$	4,215
2017	$	3,944

Other Non-Current Assets

We have included deferred debt issuance costs in other assets. We amortize deferred debt issuance costs as interest expense over the life of the related debt. The following summarizes the changes in the carrying amount of these assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	5,723		$	8,102		$	1,898
Additions		4,902			82			9,994
Interest expense – debt issuance costs		(2,157	)		(2,461	)		(3,790	)
Balance at end of period	$	8,468		$	5,723		$	8,102

Capitalization of Interest Cost

We capitalize interest in accordance with FASB Topic Interest. We incurred total interest of $4.9 million, $6.1 million and $14.8 million in the years ended December 31, 2012, 2011 and 2010, respectively, of which we capitalized $1.2 million, $1.6 million and $1.9 million in the years ended December 31, 2012, 2011 and 2010, respectively.

Cash and Cash Equivalents and Restricted Cash

Our cash equivalents are highly liquid investments, with maturities of three months or less when we purchase them.

We record cash and cash equivalents as restricted when we are unable to freely use such cash and cash equivalents for our general operating purposes. At December 31, 2012, we had restricted cash and cash equivalents totaling $63.9 million, $8.0 million of which was held in restricted foreign cash accounts, $2.9 million of which was held for future decommissioning of facilities (which is included in other assets on our consolidated balance sheets), $51.9 million of which was held to meet reinsurance reserve requirements of our captive insurer (in lieu of long-term investments), and $1.1 million of which was held in money market funds maintained by our captive insurer.

Derivative Financial Instruments

Our global operations give rise to exposure to market risks from changes in foreign exchange rates. We use derivative financial instruments to reduce the impact of changes in foreign exchange rates on our operating results. We use these instruments primarily to hedge our exposure associated with revenues or costs on our long-term contracts that are denominated in currencies other than our operating entities’ functional currencies. We do not hold or issue financial instruments for trading or other speculative purposes.

We enter into derivative financial instruments primarily as hedges of certain firm purchase and sale commitments denominated in foreign currencies. We record these contracts at fair value on our consolidated balance sheets. Depending on the hedge designation at the inception of the contract, the related gains and losses on these contracts are either deferred in stockholders’ equity (as a component of accumulated other comprehensive income) until the hedged item is recognized in earnings or offset against the change in fair value of the hedged firm commitment through earnings. Any ineffective portion of a derivative’s change in fair value is immediately recognized in earnings. The gain or loss on a derivative financial instrument not designated as a hedging instrument is also immediately recognized in earnings. Gains and losses on derivative financial instruments that require immediate recognition are included as a component of other income (expense) – net in our consolidated and combined statements of income.

Self-Insurance

We have a wholly owned insurance subsidiary that provides employer’s liability, general and automotive liability and workers’ compensation insurance and, from time to time, builder’s risk insurance (within certain limits) to our companies. We may also, in the future, have this insurance subsidiary accept other risks that we cannot or do not wish to transfer to outside insurance companies. Included in other liabilities on our consolidated balance sheets are reserves for self-insurance totaling $42.8 million and $43.6 million at December 31, 2012 and 2011, respectively. The reduction in 2012 was primarily attributable to a change in estimate recognized in cost of operations in our consolidated and combined statements of income.

Loss Contingencies

We estimate liabilities for loss contingencies when it is probable that a liability has been incurred and the amount of loss is reasonably estimable. We provide disclosure when there is a reasonable possibility that the ultimate loss will exceed the recorded provision or if such probable loss is not reasonably estimable. We are currently involved in some significant litigation, as discussed in Note 10. Our losses are typically resolved over long periods of time and are often difficult to assess and estimate due to, among other reasons, the possibility of multiple actions by third parties; the attribution of damages, if any, among multiple defendants; plaintiffs, in most cases involving personal injury claims, do not specify the amount of damages claimed; the discovery process may take multiple years to complete; during the litigation process, it is common to have multiple complex unresolved procedural and substantive issues; the potential availability of insurance and indemnity coverages; the wide-ranging outcomes reached in similar cases, including the variety of damages awarded; the likelihood of settlements for de minimus amounts prior to trial; the likelihood of success at trial; and the likelihood of success on appeal. Consequently, it is possible future earnings could be affected by changes in our assessments of the probability that a loss has been incurred in a material pending litigation against us and/or changes in our estimates related to such matters.

Stock-Based Compensation

We expense stock-based compensation in accordance with FASB Topic Compensation – Stock Compensation. Under this topic, the fair value of equity-classified awards, such as restricted stock, performance shares and stock options, is determined on the date of grant and is not remeasured. The fair value of liability-classified awards, such as cash-settled stock appreciation rights, restricted stock units and performance units, is determined on the date of grant and is remeasured at the end of each reporting period through the date of settlement. Grant date fair values for restricted stock, restricted stock units, performance shares and performance units are determined using the closing price of our common stock on the date of grant. Grant date fair values for stock options and stock appreciation rights are determined using a Black-Scholes option-pricing model (“Black-Scholes”). The determination of the fair value of a share-based payment award using an option-pricing model requires the input of highly subjective assumptions, such as the expected life of the award and stock price volatility. Prior to August 1, 2010, all of our stock-based compensation expense was attributable to our participation in MII legacy stock-based compensation plans. Expense recognized prior to August 1, 2010 was based on the fair value of MII’s stock-based compensation awards.

Under the provisions of this FASB topic, we recognize expense, net of an estimated forfeiture rate, for all share-based awards granted on a straight-line basis over the requisite service periods of the awards, which is generally equivalent to the vesting term. This topic requires compensation expense to be recognized, net of an estimate for forfeitures, such that compensation expense is recorded only for those awards expected to vest. We review the estimate for forfeitures periodically and record any adjustments deemed necessary for each reporting period. If our actual forfeiture rate is materially different from our estimate, the stock-based compensation expense could be significantly different from what we have recorded in the current period.

Additionally, this FASB topic amended FASB Topic Statement of Cash Flows, to require excess tax benefits to be reported as a financing cash flow, rather than as a reduction of taxes paid. These excess tax benefits result from tax deductions in excess of the cumulative compensation expense recognized for options exercised and other equity-classified awards.

See Note 9 for a further discussion of stock-based compensation.

Recently Adopted Accounting Standards

In September 2011, the Financial Accounting Standards Board (“FASB”) issued an update to Topic Intangibles—Goodwill and Other. This update permits an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform the two-step goodwill impairment test currently required under this topic. On January 1, 2012, we adopted this update. The adoption of these provisions did not have an impact on our financial statements.

In June 2011, the FASB issued an update to Topic Comprehensive Income. This update requires that comprehensive income be presented either in a single continuous statement or in two separate but consecutive statements. In the two-statement approach, the first statement would present the components of net income consistent with the statement of income format currently utilized and the second statement would present total other comprehensive income, the components of other comprehensive income, and the total of comprehensive income. There are no changes to the components that must be reported in other comprehensive income or when a component of other comprehensive income must be reclassified to net income. On January 1, 2012, we adopted this update. The adoption of these provisions did not have an impact on our financial statements.

In May 2011, the FASB issued an update to Topic Fair Value Measurement. This update reflects joint efforts by the FASB and International Accounting Standards Board to develop a converged fair value framework on how to measure fair value and what fair value measurement disclosures to provide. On January 1, 2012, we adopted this update. The adoption of these provisions did not have an impact on our financial statements.

New Accounting Standards

In July 2012, the FASB issued an update to Topic Intangibles—Goodwill and Other. This update permits an entity to first assess qualitative factors to determine whether it is more likely than not that an indefinite-lived intangible asset is impaired as a basis for determining whether it is necessary to perform the quantitative impairment test currently required under this topic. This update will be effective for us in 2013. We do not expect the adoption of this update to impact our financial statements.

In February 2013, the FASB issued an update to Topic Comprehensive Income. This update requires an entity to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to present, either on the face of the statement of income or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts. This update will be effective for us in 2013. We do not expect the adoption of this update to have a material impact on our financial statements.

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Quarterly Financial Data (Selected Quarterly Financial Information) (Detail) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended																12 Months Ended
	Dec. 31, 2012		Sep. 30, 2012		Jun. 30, 2012		Mar. 31, 2012		Dec. 31, 2011		Sep. 30, 2011		Jun. 30, 2011		Mar. 31, 2011		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Quarterly Financial Data [Line Items]
Revenues	$ 865,296		$ 807,586		$ 852,585		$ 765,892		$ 800,789		$ 707,622		$ 752,352		$ 691,277		$ 3,291,359	[1],[2]	$ 2,952,040	[1],[2]	$ 2,688,811	[1],[2]
Operating income(1)	65,693	[3]	84,399	[3]	110,077	[3]	86,420	[3]	(103,444)	[3]	74,912	[3]	82,809	[3]	41,394	[3]	346,589	[4]	95,671	[4]	248,855	[4]
Equity in Income of Investees	18,119		14,546		16,687		17,357		22,131		22,782		18,381		15,361		66,709		78,655		74,082
Net income attributable to The Babcock & Wilcox Company	$ 39,071		$ 51,443		$ 77,231		$ 59,950		$ (63,009)		$ 56,742		$ 58,665		$ 25,921		$ 227,695		$ 78,319		$ 139,939
Net income attributable to The Babcock & Wilcox Company, Basic earnings per common share	$ 0.33		$ 0.43		$ 0.65		$ 0.51		$ (0.53)		$ 0.48		$ 0.50		$ 0.22		$ 1.92		$ 0.67		$ 1.20
Net income attributable to The Babcock & Wilcox Company, Diluted earnings per common share	$ 0.33		$ 0.43		$ 0.65		$ 0.50		$ (0.53)		$ 0.48		$ 0.50		$ 0.22		$ 1.91		$ 0.66		$ 1.19

[1] We allocate geographic revenues based on the location of the customer's operations.

[2] Segment revenues are net of the following intersegment transfers and other adjustments:

[3] Includes equity in income of investees.

[4] (2) Included in operating income is the following:

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Equity Method Investments (Summary Of Combined Income Statement Information) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule of Variable Interest Entities for Loans to Commercial Borrowers [Line Items]
Revenues	$ 2,758,159	$ 2,669,923	$ 2,283,256
Gross profit	210,425	271,920	258,598
Income before provision for income taxes	146,911	185,859	182,482
Provision for income taxes	9,000	14,258	21,230
Net Income	$ 137,911	$ 171,601	$ 161,252

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Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2012

Computation Of Basic And Diluted Earnings Per Share

The following table sets forth the computation of basic and diluted earnings per share:

	Year Ended December 31,
	2012		2011		2010
	(In thousands, except shares and per share amounts)
Basic:
Net income attributable to The Babcock & Wilcox Company	$	227,695	$	78,319	$	139,939
Weighted average common shares		118,418,930		117,560,594		116,260,425
Basic earnings per common share:
Net income attributable to The Babcock & Wilcox Company	$	1.92	$	0.67	$	1.20
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	227,695	$	78,319	$	139,939
Weighted average common shares (basic)		118,418,930		117,560,594		116,260,425
Effect of dilutive securities:
Stock options, restricted stock and performance shares(1)		602,394		844,003		1,365,640
Adjusted weighted average common shares		119,021,324		118,404,597		117,626,065
Diluted earnings per common share:
Net income attributable to The Babcock & Wilcox Company	$	1.91	$	0.66	$	1.19

(1) At December 31, 2012, 2011 and 2010, we excluded from the diluted share calculation 1,082,904, 742,035 and 349,744 shares, respectively, related to stock options, as their effect would have been antidilutive.

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Basis Of Presentation And Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2012

Pension Accounting Change

Pension Accounting Change

In the fourth quarter of 2012, we elected to change our accounting method for recognizing actuarial gains and losses for our pension and other postretirement benefit plans. Historically, these gains and losses were recognized as a component of accumulated other comprehensive income on our consolidated balance sheets and we amortized these actuarial gains and losses into earnings over the average remaining service period for our Canadian plans to the extent such gains and losses exceeded a corridor and for our domestic plans we used an amortization method over the average remaining service period without the use of a corridor. Under our new accounting method, we will immediately recognize actuarial gains and losses into earnings in the fourth quarter each year as a component of net periodic benefit cost. This new accounting method results in actuarial gains and losses being recognized faster than our previous amortization method. We believe the new accounting method is preferable as this accelerated method recognizes the effects of plan investment performance, interest rate movements and changes in other actuarial assumptions as a component of earnings in the period they occur. This change has been reported through retrospective application of the new accounting method to all periods presented. See Note 6 for a further discussion of our pension and postretirement benefits and Note 20 for disclosures relating to the effect of this change in our accounting method.

Business Segments

Business Segments

We operate in four business segments: Power Generation, Nuclear Operations, Technical Services and Nuclear Energy. For financial information about our segments, see Note 17 to our consolidated and combined financial statements included in this report.

Our segments are further described as follows:

• Our Power Generation segment supplies boilers fired with fossil fuels, such as coal, oil and natural gas, or renewable fuels such as biomass and municipal solid waste. In addition, we supply environmental equipment and components and related services to customers in different regions around the world. This segment owns or leases manufacturing facilities in the U.S., Canada, Denmark, Germany, Mexico, China and Scotland. We design, engineer, manufacture, supply, construct and service large utility and industrial power generation systems, including boilers used to generate steam in electric power plants, pulp and paper making, chemical and process applications and other industrial uses. We also provide the same compliment of services for our renewable portfolio of boiler technology, which includes biomass fired, waste-to-energy and concentrated solar energy for steam generating solutions. In addition, this segment is a technological leader in providing cost-effective and efficient air pollution control solutions and material handling systems. We have successfully developed advanced technologies to control nitrogen oxides, sulfur dioxide, fine particulate, mercury, acid gases and other hazardous air emissions. In addition, our Power Generation segment offers a variety of construction services for the entire balance of plant, from large steam generation or environmental equipment projects, to cogeneration and combined cycle installations. This segment also offers a full suite of aftermarket services. Our Power Generation segment’s full-scope boiler, environmental and auxiliary equipment retrofits, upgrades and services improve plant performance and efficiency and extend the life of vital steam generating assets.

• Our Nuclear Operations segment manufactures naval nuclear reactors for the U.S. Department of Energy (“DOE”)/National Nuclear Security Administration’s (“NNSA”) Naval Nuclear Propulsion Program, which in turn supplies them to the U.S. Navy for use in submarines and aircraft carriers. Through this segment, we own and operate manufacturing facilities located in Lynchburg, Virginia; Mount Vernon, Indiana; Euclid, Ohio; Barberton, Ohio; and Erwin, Tennessee. The Barberton, Ohio and Mount Vernon, Indiana locations specialize in the design and manufacture of heavy components. These two locations are N-Stamp accredited by the American Society of Mechanical Engineers (“ASME”), making them two of only a few North American suppliers of large, heavy-walled nuclear components and vessels. The Euclid, Ohio facility, which is also ASME N-Stamp certified, fabricates electro-mechanical equipment for the U.S. Government, and performs design, manufacturing, inspection, assembly and testing activities. The Lynchburg, Virginia operations fabricate fuel-bearing precision components that range in weight from a few grams to hundreds of tons. In-house capabilities also include wet chemistry uranium processing, advanced heat treatment to optimize component material properties and a controlled, clean-room environment with the capacity to assemble railcar-size components. Fuel for the naval nuclear reactors is provided by Nuclear Fuel Services, Inc. (“NFS”), one of our wholly owned subsidiaries. Located in Erwin, Tennessee, NFS also converts cold war-era government stockpiles of highly enriched uranium into material suitable for further processing into commercial nuclear reactor fuel.

• Our Technical Services segment provides various services to the U.S. Government, including uranium processing, environmental site restoration services and management and operating services for various U.S. Government-owned facilities. These services are provided to the DOE, including the NNSA, the Office of Nuclear Energy, the Office of Science, the Department of Defense and the Office of Environmental Management, and through this segment we deliver products and management solutions to nuclear operations and high-consequence manufacturing facilities. A significant portion of this segment’s operations are conducted through joint ventures.

• Our Nuclear Energy segment supplies commercial nuclear steam generators and components to nuclear utility customers. In addition, this segment is actively designing the modular and scalable B&W mPower^TM reactor. B&W has supplied the nuclear industry with more than 1,300 large, heavy components worldwide. With manufacturing operations in the U.S. and Canada, this segment is the only heavy nuclear component, N-Stamp certified manufacturer in North America. Our Nuclear Energy segment fabricates pressure vessels, reactors, steam generators, heat exchangers and other auxiliary equipment. This segment also provides specialized engineering services that include structural component design, 3-D thermal-hydraulic engineering analysis, weld and robotic process development and metallurgy and materials engineering. Our Nuclear Energy segment also provides power plant construction and management and maintenance services. In addition, this segment offers services for nuclear steam generators and balance of plant equipment, as well as nondestructive examination and tooling/repair solutions for other plant systems and components.

The consolidated results of operations, financial position and cash flows for the year ended December 31, 2012 are not necessarily indicative of the results that may be expected for the year ending December 31, 2013.

Use Of Estimates

Use of Estimates

We use estimates and assumptions to prepare our financial statements in conformity with GAAP. Some of our more significant estimates include our estimate of costs to complete long-term construction contracts and estimates we make in selecting assumptions related to the valuations of our pension and postretirement plans, including the selection of our discount rates and expected rates of return on our pension plan assets. These estimates and assumptions affect the amounts we report in our financial statements and accompanying notes. Our actual results could differ from these estimates. Variances could result in a material effect on our financial condition and results of operations in future periods.

Earnings Per Share

Earnings Per Share

We have computed earnings per common share on the basis of the weighted average number of common shares, and, where dilutive, common share equivalents, outstanding during the indicated periods. On July 30, 2010, 116,225,732 shares of our common stock were distributed to MII shareholders to complete our spin-off from MII. For comparative purposes, and to provide a more meaningful calculation of weighted average shares, we have assumed this amount to be outstanding as of the beginning of each period presented prior to our spin-off in our calculation of basic weighted average shares. In addition, for our dilutive weighted average share calculations, we have assumed the dilutive securities outstanding at July 30, 2010 were also outstanding at each of the periods presented prior to our spin-off.

Investments

Investments

Our investments, primarily U.S. Government obligations and other highly liquid money market instruments, are classified as available-for-sale and are carried at fair value, with the unrealized gains and losses, net of tax, reported as a component of accumulated other comprehensive income. We classify investments available for current operations in the consolidated balance sheets as current assets, while we classify investments held for long-term purposes as noncurrent assets. We adjust the amortized cost of debt securities for amortization of premiums and accretion of discounts to maturity. That amortization is included in interest income. We include realized gains and losses on our investments in other income (expense) – net. The cost of securities sold is based on the specific identification method. We include interest on securities in interest income.

Foreign Currency Translation

Foreign Currency Translation

We translate assets and liabilities of our foreign operations into U.S. dollars at current exchange rates, and we translate income statement items at average exchange rates for the periods presented. We record adjustments resulting from the translation of foreign currency financial statements as a component of accumulated other comprehensive income. We report foreign currency transaction gains and losses in income. We have included in other income (expense)—net transaction losses of $0.6 million, $1.9 million and $6.5 million for the years ended December 31, 2012, 2011 and 2010, respectively.

Contracts and Revenue Recognition

Contracts and Revenue Recognition

We generally recognize contract revenues and related costs on a percentage-of-completion method for individual contracts or combinations of contracts based on work performed, man hours, or a cost-to-cost method, as applicable to the product or activity involved. We recognize estimated contract revenue and resulting income based on the measurement of the extent of progress completion as a percentage of the total project. Certain costs may be excluded from the cost-to-cost method of measuring progress, such as significant costs for materials and major third party subcontractors, if it appears that such exclusion would result in a more meaningful measurement of actual contract progress and resulting periodic allocation of income. We include revenues and related costs so recorded, plus accumulated contract costs that exceed amounts invoiced to customers under the terms of the contracts, in contracts in progress. We include in advance billings on contracts billings that exceed accumulated contract costs and revenues and costs recognized under the percentage-of-completion method. Most long-term contracts contain provisions for progress payments. Our unbilled receivables do not contain an allowance for credit losses as we expect to invoice customers and collect all amounts for unbilled revenues. We review contract price and cost estimates periodically as the work progresses and reflect adjustments proportionate to the percentage-of-completion in income in the period when those estimates are revised. For all contracts, if a current estimate of total contract cost indicates a loss on a contract, the projected loss is recognized in full when determined.

For contracts as to which we are unable to estimate the final profitability except to assure that no loss will ultimately be incurred, we recognize equal amounts of revenue and cost until the final results can be estimated more precisely. For these deferred profit recognition contracts, we recognize revenue and cost equally and only recognize gross margin when probable and reasonably estimable, which we generally determine to be when the contract is approximately 70% complete. We treat long-term construction contracts that contain such a level of risk and uncertainty that estimation of the final outcome is impractical, except to assure that no loss will be incurred, as deferred profit recognition contracts.

Our policy is to account for fixed-price contracts under the completed-contract method if we believe that we are unable to reasonably forecast cost to complete at start-up. Under the completed-contract method, income is recognized only when a contract is completed or substantially complete.

For the majority of parts orders and certain aftermarket services activities, we recognize revenues as goods are delivered and work is performed.

Variations from estimated contract performance could result in material adjustments to operating results for any fiscal quarter or year. We include claims for extra work or changes in scope of work to the extent of costs incurred in contract revenues when we believe collection is probable.

In the year ended December 31, 2012, we recorded a contract loss totaling approximately $16.9 million, net of claims, based on our estimate of costs to complete a project in our Power Generation segment. In the year ended December 31, 2011, we recorded additional costs totaling approximately $61.8 million ($50.7 million in our Nuclear Energy segment and $11.1 in our Nuclear Operations segment) to complete certain projects attributable to changes in estimate due to productivity and scheduling issues. In May 2012, we entered into an agreement with the customer of the Nuclear Energy project to settle contract claims resulting in recognition of revenues totaling approximately $18.4 million in 2012. These projects are now complete.

Some of our contracts contain provisions that require us to pay liquidated damages if we are responsible for the failure to meet specified contractual milestone dates and the applicable customer asserts a claim under these provisions. These contracts define the conditions and timing under which our customers may make claims against us for liquidated damages. In the majority of cases in which we have had potential exposure for liquidated damages, such damages ultimately were determined not to be caused by our actions or were not otherwise asserted by our customers. Accordingly, we do not accrue liabilities for liquidated damages unless probable and estimable. As of December 31, 2012, we had not accrued for approximately $6.0 million of potential liquidated damages that are not currently due under the particular contract but which we believe could be asserted based upon our current expectations of the time to complete a certain project in our Power Generation segment. We do not believe any of these potential liquidated damages are probable of being assessed due primarily to their relationship to unforeseen worksite conditions that we believe are the responsibility of our customer. We are in active discussions with our customer on the issues giving rise to delays in this project, and we believe we will be successful in obtaining schedule extensions that should resolve the potential for liquidated damages liability. However, we may not achieve relief on some or all of the issues.

The following represent the components of our contracts in progress and advance billings on contracts included in our consolidated balance sheets:

	December 31,
	2012			2011
	(In thousands)
Included in Contracts in Progress:
Costs incurred less costs of revenue recognized	$	135,972		$	135,513
Revenues recognized less billings to customers		180,546			179,773
Contracts In Progress	$	316,518		$	315,286
Included In Advance Billings on Contracts:
Billings to customers less revenues recognized	$	541,983		$	492,106
Costs incurred less costs of revenue recognized		(69,696	)		(53,353	)
Advance Billings on Contracts	$	472,287		$	438,753

The following amounts represent retainages on contracts:

	December 31,
	2012		2011
	(In thousands)
Retainages expected to be collected within one year	$	85,776	$	60,158
Retainages expected to be collected after one year		28,661		14,526
Total retainages	$	114,437	$	74,684

We have included in accounts receivable – trade retainages expected to be collected in 2013. Retainages expected to be collected after one year are included in other assets. Of the long-term retainages at December 31, 2012, we anticipate collecting $23.1 million in 2014, $2.9 million in 2015 and $2.7 million in 2016.

Comprehensive Income

Comprehensive Income

The components of accumulated other comprehensive income included in stockholders’ equity are as follows:

	December 31,
	2012			2011
	(In thousands)
Currency translation adjustments	$	40,899		$	36,626
Net unrealized gain on investments		597			201
Net unrealized gain on derivative financial instruments		2,103			2,717
Unrecognized prior service cost on benefit obligations		(10,871	)		(12,718	)
Accumulated other comprehensive income	$	32,728		$	26,826

Warranty Expense

Warranty Expense

We accrue estimated expense, included in cost of operations on our consolidated and combined statements of income, to satisfy contractual warranty requirements when we recognize the associated revenue on the related contracts. In addition, we make specific provisions or reductions where we expect the actual warranty costs to significantly differ from the accrued estimates. Such changes could have a material effect on our consolidated financial condition, results of operations and cash flows.

The following summarizes the changes in the carrying amount of accrued warranty expense:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	97,209		$	109,588		$	115,055
Additions		20,972			21,267			31,660
Expirations and other changes		(24,766	)		(14,288	)		(28,032	)
Charges		(10,217	)		(19,035	)		(10,532	)
Translation and other		484			(323	)		1,437
Balance at end of period	$	83,682		$	97,209		$	109,588

Asset Retirement Obligations and Environmental Clean-up Costs

Asset Retirement Obligations and Environmental Clean-up Costs

We accrue for future decommissioning of our nuclear facilities that will permit the release of these facilities to unrestricted use at the end of each facility’s life, which is a requirement of our licenses from the U.S. Nuclear Regulatory Commission (the “NRC”). In accordance with the FASB Topic Asset Retirement and Environmental Obligations, we record the fair value of a liability for an asset retirement obligation in the period in which it is incurred. When we initially record such a liability, we capitalize a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of a liability, we will settle the obligation for its recorded amount or incur a gain or loss. This topic applies to environmental liabilities associated with assets that we currently operate and are obligated to remove from service. For environmental liabilities associated with assets that we no longer operate, we have accrued amounts based on the estimated costs of clean-up activities for which we are responsible, net of any cost-sharing arrangements. We adjust the estimated costs as further information develops or circumstances change. An exception to this accounting treatment relates to the work we perform for two facilities for which the U.S. Government is obligated to pay substantially all of the decommissioning costs.

Substantially all of our asset retirement obligations relate to the remediation of our nuclear analytical laboratory and the NFS facility in our Nuclear Operations segment. The following table reflects our asset retirement obligations:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Balance at beginning of period	$	35,885	$	32,657		$	29,491
Costs incurred		—		(2,265	)		—
Additions/Adjustments		3,422		2,935			—
Accretion		3,059		2,558			3,166
Balance at end of period	$	42,366	$	35,885		$	32,657

Research and Development

Research and Development

Our research and development activities are related to the development and improvement of new and existing products and equipment, as well as conceptual and engineering evaluation for translation into practical applications. We charge to research and development cost the costs of research and development unrelated to specific contracts as incurred. Substantially all of these costs are in our Power Generation and Nuclear Energy segments and include costs related to the development of our modular nuclear reactor business, B&W mPower^TM. Contractual arrangements for customer-sponsored research and development can vary on a case-by-case basis and include contracts, cooperative agreements and grants. Research and development activities (including in-kind research and development services described below) totaled $173.9 million, $163.0 million and $102.1 million in the years ended December 31, 2012, 2011 and 2010, respectively, which include amounts paid for by our customers of $53.4 million, $56.6 million and $32.9 million, respectively.

During the years ended December 31, 2012 and 2011, we recognized $17.9 million and $16.6 million, respectively, of non-cash in-kind research and development costs (included above) related to services contributed by our minority partner to Generation mPower LLC (“GmP”), our majority-owned subsidiary formed in 2011 to oversee the program to develop the small modular nuclear power plant based on B&W mPower^TM technology.

In November 2012, our Nuclear Energy segment was selected as the winner of the DOE’s competitively bid Small Modular Reactor (“SMR”) Licensing Technical Support Program, and will receive funding that will support accelerated development of its B&W mPower™ SMR technology.

Income Taxes

Income Taxes

Income tax expense for federal, foreign, state and local income taxes are calculated on pre-tax income based on current tax law and include the cumulative effect of any changes in tax rates from those used previously in determining deferred tax assets and liabilities. We record a valuation allowance to reduce our deferred tax assets to the amount that is more likely than not to be realized. We assess deferred taxes and the adequacy of the valuation allowance on a quarterly basis. In the ordinary course of business there is inherent uncertainty in quantifying our income tax positions. We assess our income tax positions and record tax benefits for all years subject to examination based upon management’s evaluation of the facts, circumstances, and information available at the reporting date. For those tax positions where it is more-likely-than-not that a tax benefit will be sustained, we have recorded the largest amount of tax benefit with a greater than 50% likelihood of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. For those income tax positions where it is not more-likely-than-not that a tax benefit will be sustained, no tax benefit has been recognized in the financial statements. We record interest and penalties (net of any applicable tax benefit) related to income taxes as a component of provision for income taxes on our consolidated and combined statements of income.

Inventories

Inventories

We carry our inventories at the lower of cost or market. We determine cost principally on the first-in, first-out basis, except for certain materials inventories of our Power Generation segment, for which we use the last-in, first-out (“LIFO”) method. We determined the cost of approximately 17% and 19% of our total inventories using the LIFO method at December 31, 2012 and 2011, respectively, and our total LIFO reserve at December 31, 2012 and 2011 was approximately $7.5 million and $7.1 million, respectively. Inventories are summarized below:

	December 31,
	2012		2011
	(In thousands)
Raw Materials and Supplies	$	98,428	$	77,932
Work in Progress		7,956		6,889
Finished Goods		17,834		22,477
Total Inventories	$	124,218	$	107,298

Property, Plant and Equipment

Property, Plant and Equipment

We carry our property, plant and equipment at depreciated cost, less any impairment provisions.

We depreciate our property, plant and equipment using the straight-line method over estimated economic useful lives of eight to 40 years for buildings and two to 28 years for machinery and equipment. Our depreciation expense was $59.4 million, $61.8 million and $61.1 million for the years ended December 31, 2012, 2011 and 2010, respectively.

We expense the costs of maintenance, repairs and renewals that do not materially prolong the useful life of an asset as we incur them.

Property, plant and equipment is stated at cost and is set forth below:

	December 31,
	2012		2011
	(In thousands)
Land	$	11,875	$	11,656
Buildings		241,281		224,661
Machinery and equipment		776,678		710,666
Property under construction		69,206		70,439
		1,099,040		1,017,422
Less accumulated depreciation		652,019		595,131
Net Property, Plant and Equipment	$	447,021	$	422,291

Investments in Unconsolidated Affiliates

Investments in Unconsolidated Affiliates

We use the equity method of accounting for affiliates in which we are able to exert significant influence. Currently, substantially all of our material investments in affiliates that are not consolidated are recorded using the equity method. Affiliates in which our investment ownership is less than 20% and where we are unable to exert significant influence are carried at cost.

Goodwill

Goodwill

The following summarizes the changes in the carrying amount of goodwill:

	Power Generation		Nuclear Operations			Technical Services		Nuclear Energy		Total
	(In thousands)
Balance at December 31, 2010	$	88,042	$	122,407		$	45,000	$	13,975	$	269,424
Acquisition of Loibl (Note 2)		11,015		—			—		—		11,015
Foreign currency translation adjustments and other		45		(4,304	)		—		—		(4,259	)
Balance at December 31, 2011	$	99,102	$	118,103		$	45,000	$	13,975	$	276,180
Purchase price adjustment for acquisition of Loibl (Note 2)		3,727		—			—		—		3,727
Foreign currency translation adjustments and other		873		—			—		—		873
Balance at December 31, 2012	$	103,702	$	118,103		$	45,000	$	13,975	$	280,780

Intangible Assets

Intangible Assets

We report our intangible assets in other assets. We amortize those intangible assets with definite lives to operating expense using the straight-line method.

Other assets include the following intangible assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Amortized intangible assets:
Gross cost:
Customer relationships	$	36,644		$	40,051		$	37,167
Acquired backlog		2,979			22,435			19,335
Tradename		11,945			15,169			12,291
Unpatented technology		6,422			6,402			5,902
Patented technology		6,961			6,961			6,625
All other		7,912			7,901			11,935
Total	$	72,863		$	98,919		$	93,255
Accumulated amortization:
Customer relationships	$	(11,173	)	$	(8,618	)	$	(6,026	)
Acquired backlog		(1,457	)		(17,040	)		(12,701	)
Tradename		(6,422	)		(6,509	)		(4,260	)
Unpatented technology		(2,682	)		(2,033	)		(1,407	)
Patented technology		(4,235	)		(3,219	)		(2,096	)
All other		(4,343	)		(3,594	)		(6,296	)
Total	$	(30,312	)	$	(41,013	)	$	(32,786	)
Net amortized intangible assets	$	42,551		$	57,906		$	60,469
Unamortized intangible assets:
NRC category 1 license	$	43,830		$	43,830		$	43,830
Trademarks and trade names		1,305			1,305			1,305
Total unamortized intangible assets	$	45,135		$	45,135		$	45,135

The following summarizes the changes in the carrying amount of intangible assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	103,041		$	105,604		$	103,379
Business acquisitions & adjustments		(1,746	)		9,100			14,280
Amortization expense		(11,010	)		(11,545	)		(11,679	)
Impairment charge		(3,216	)		—			—
Foreign currency translation adjustments and other		617			(118	)		(376	)
Balance at end of period	$	87,686		$	103,041		$	105,604

We recognized an impairment charge totaling $3.2 million in the year ended December 31, 2012 related to the cancellation of an operations and maintenance services contract in our Power Generation segment.

The estimated amortization expense for the next five fiscal years is as follows (in thousands):

Year Ending December 31,	Amount
2013	$	8,023
2014	$	5,494
2015	$	4,292
2016	$	4,215
2017	$	3,944

Other Non-Current Assets

Other Non-Current Assets

We have included deferred debt issuance costs in other assets. We amortize deferred debt issuance costs as interest expense over the life of the related debt. The following summarizes the changes in the carrying amount of these assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	5,723		$	8,102		$	1,898
Additions		4,902			82			9,994
Interest expense – debt issuance costs		(2,157	)		(2,461	)		(3,790	)
Balance at end of period	$	8,468		$	5,723		$	8,102

Capitalization Of Interest Cost

Capitalization of Interest Cost

We capitalize interest in accordance with FASB Topic Interest. We incurred total interest of $4.9 million, $6.1 million and $14.8 million in the years ended December 31, 2012, 2011 and 2010, respectively, of which we capitalized $1.2 million, $1.6 million and $1.9 million in the years ended December 31, 2012, 2011 and 2010, respectively.

Cash and Cash Equivalents and Restricted Cash

Cash and Cash Equivalents and Restricted Cash

Our cash equivalents are highly liquid investments, with maturities of three months or less when we purchase them.

We record cash and cash equivalents as restricted when we are unable to freely use such cash and cash equivalents for our general operating purposes. At December 31, 2012, we had restricted cash and cash equivalents totaling $63.9 million, $8.0 million of which was held in restricted foreign cash accounts, $2.9 million of which was held for future decommissioning of facilities (which is included in other assets on our consolidated balance sheets), $51.9 million of which was held to meet reinsurance reserve requirements of our captive insurer (in lieu of long-term investments), and $1.1 million of which was held in money market funds maintained by our captive insurer.

Derivative Financial Instruments

Derivative Financial Instruments

Our global operations give rise to exposure to market risks from changes in foreign exchange rates. We use derivative financial instruments to reduce the impact of changes in foreign exchange rates on our operating results. We use these instruments primarily to hedge our exposure associated with revenues or costs on our long-term contracts that are denominated in currencies other than our operating entities’ functional currencies. We do not hold or issue financial instruments for trading or other speculative purposes.

We enter into derivative financial instruments primarily as hedges of certain firm purchase and sale commitments denominated in foreign currencies. We record these contracts at fair value on our consolidated balance sheets. Depending on the hedge designation at the inception of the contract, the related gains and losses on these contracts are either deferred in stockholders’ equity (as a component of accumulated other comprehensive income) until the hedged item is recognized in earnings or offset against the change in fair value of the hedged firm commitment through earnings. Any ineffective portion of a derivative’s change in fair value is immediately recognized in earnings. The gain or loss on a derivative financial instrument not designated as a hedging instrument is also immediately recognized in earnings. Gains and losses on derivative financial instruments that require immediate recognition are included as a component of other income (expense) – net in our consolidated and combined statements of income.

Self-Insurance

Self-Insurance

We have a wholly owned insurance subsidiary that provides employer’s liability, general and automotive liability and workers’ compensation insurance and, from time to time, builder’s risk insurance (within certain limits) to our companies. We may also, in the future, have this insurance subsidiary accept other risks that we cannot or do not wish to transfer to outside insurance companies. Included in other liabilities on our consolidated balance sheets are reserves for self-insurance totaling $42.8 million and $43.6 million at December 31, 2012 and 2011, respectively. The reduction in 2012 was primarily attributable to a change in estimate recognized in cost of operations in our consolidated and combined statements of income.

Loss Contingencies

Loss Contingencies

We estimate liabilities for loss contingencies when it is probable that a liability has been incurred and the amount of loss is reasonably estimable. We provide disclosure when there is a reasonable possibility that the ultimate loss will exceed the recorded provision or if such probable loss is not reasonably estimable. We are currently involved in some significant litigation, as discussed in Note 10. Our losses are typically resolved over long periods of time and are often difficult to assess and estimate due to, among other reasons, the possibility of multiple actions by third parties; the attribution of damages, if any, among multiple defendants; plaintiffs, in most cases involving personal injury claims, do not specify the amount of damages claimed; the discovery process may take multiple years to complete; during the litigation process, it is common to have multiple complex unresolved procedural and substantive issues; the potential availability of insurance and indemnity coverages; the wide-ranging outcomes reached in similar cases, including the variety of damages awarded; the likelihood of settlements for de minimus amounts prior to trial; the likelihood of success at trial; and the likelihood of success on appeal. Consequently, it is possible future earnings could be affected by changes in our assessments of the probability that a loss has been incurred in a material pending litigation against us and/or changes in our estimates related to such matters.

Stock-Based Compensation

Stock-Based Compensation

We expense stock-based compensation in accordance with FASB Topic Compensation – Stock Compensation. Under this topic, the fair value of equity-classified awards, such as restricted stock, performance shares and stock options, is determined on the date of grant and is not remeasured. The fair value of liability-classified awards, such as cash-settled stock appreciation rights, restricted stock units and performance units, is determined on the date of grant and is remeasured at the end of each reporting period through the date of settlement. Grant date fair values for restricted stock, restricted stock units, performance shares and performance units are determined using the closing price of our common stock on the date of grant. Grant date fair values for stock options and stock appreciation rights are determined using a Black-Scholes option-pricing model (“Black-Scholes”). The determination of the fair value of a share-based payment award using an option-pricing model requires the input of highly subjective assumptions, such as the expected life of the award and stock price volatility. Prior to August 1, 2010, all of our stock-based compensation expense was attributable to our participation in MII legacy stock-based compensation plans. Expense recognized prior to August 1, 2010 was based on the fair value of MII’s stock-based compensation awards.

Under the provisions of this FASB topic, we recognize expense, net of an estimated forfeiture rate, for all share-based awards granted on a straight-line basis over the requisite service periods of the awards, which is generally equivalent to the vesting term. This topic requires compensation expense to be recognized, net of an estimate for forfeitures, such that compensation expense is recorded only for those awards expected to vest. We review the estimate for forfeitures periodically and record any adjustments deemed necessary for each reporting period. If our actual forfeiture rate is materially different from our estimate, the stock-based compensation expense could be significantly different from what we have recorded in the current period.

Additionally, this FASB topic amended FASB Topic Statement of Cash Flows, to require excess tax benefits to be reported as a financing cash flow, rather than as a reduction of taxes paid. These excess tax benefits result from tax deductions in excess of the cumulative compensation expense recognized for options exercised and other equity-classified awards.

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Effect Of Accounting Change

12 Months Ended

Dec. 31, 2012

Effect Of Accounting Change

NOTE 20 – EFFECT OF ACCOUNTING CHANGE

We have retrospectively applied the new accounting method for recognizing actuarial gains and losses, as described in Note 1. We recorded a cumulative reduction to parent equity as of January 1, 2010 of $554.8 million related to this accounting method change. The impact of these adjustments on our consolidated and combined results and financial position is summarized below.

	2012						2011						2010
	New Method			Historical Method			As Adjusted			Previously Reported			As Adjusted			Previously Reported
	(In thousands, except per share amounts)
Consolidated and Combined Statements of Income:
Cost of operations	$	2,461,205		$	2,500,858		$	2,384,154		$	2,278,208		$	2,032,347		$	2,024,034
Selling, general and administrative expenses	$	428,293		$	434,673		$	447,561		$	413,210		$	412,486		$	405,682
Other income (expense)—net	$	(24,927	)	$	(24,903	)	$	2,028		$	2,168		$	(16,896	)	$	(16,400	)
Provision for income taxes	$	101,861		$	84,495		$	23,880		$	72,982		$	80,005		$	82,294
Net income	$	217,557		$	188,914		$	70,618		$	161,953		$	140,203		$	153,526
Net income attributable to The Babcock & Wilcox Company	$	227,695		$	199,052		$	78,319		$	169,654		$	139,939		$	153,262
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	1.92		$	1.68		$	0.67		$	1.44		$	1.20		$	1.32
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	1.91		$	1.67		$	0.66		$	1.43		$	1.19		$	1.30
Consolidated and Combined Statements of Comprehensive Income:
Unrecognized losses arising during the period	$	(434	)	$	(21,486	)	$	(1,205	)	$	(140,436	)	$	(551	)	$	(62,059	)
Amortization of losses included in net income	$	2,281		$	51,976		$	2,487		$	50,382		$	2,386		$	50,571
Consolidated Balances Sheets:
Capital in excess of par value	$	713,257		$	1,143,275		$	676,952		$	1,106,971
Retained earnings	$	349,063		$	455,855		$	130,890		$	266,325
Accumulated other comprehensive income (loss)	$	32,728		$	(504,082	)	$	26,826		$	(538,628	)
Consolidated and Combined Statements of Cash Flows:
Net income	$	217,557		$	188,914		$	70,618		$	161,953		$	140,203		$	153,526
Provision for (benefit from) deferred taxes	$	43,038		$	25,672		$	(19,200	)	$	29,902		$	31,168		$	33,457
Recognition of losses and prior service cost for pension and postretirement plans	$	35,480		$	78,050		$	219,508		$	79,070		$	95,547		$	79,935

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Financial Instruments with Concentrations of Credit Risk (Narrative) (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Allowance for possible losses on accounts receivable - trade	$ 3.8	$ 3.3
Government Contracts Concentration Risk [Member] | Total Revenue [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Concentration risk percentage	34.00%	38.00%

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Basis of Presentation and Significant Accounting Policies (Estimated Amortization Expense) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012
Amortization Expense Per Equivalent Unit of Production or Per Dollar of Gross Revenue [Line Items]
2013	$ 8,023
2014	5,494
2015	4,292
2016	4,215
2017	$ 3,944

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Effect Of Accounting Change (Tables)

12 Months Ended

Dec. 31, 2012

Impact of Adjustments on Consolidated and Combined Results and Financial Position

The impact of these adjustments on our consolidated and combined results and financial position is summarized below.

	2012						2011						2010
	New Method			Historical Method			As Adjusted			Previously Reported			As Adjusted			Previously Reported
	(In thousands, except per share amounts)
Consolidated and Combined Statements of Income:
Cost of operations	$	2,461,205		$	2,500,858		$	2,384,154		$	2,278,208		$	2,032,347		$	2,024,034
Selling, general and administrative expenses	$	428,293		$	434,673		$	447,561		$	413,210		$	412,486		$	405,682
Other income (expense)—net	$	(24,927	)	$	(24,903	)	$	2,028		$	2,168		$	(16,896	)	$	(16,400	)
Provision for income taxes	$	101,861		$	84,495		$	23,880		$	72,982		$	80,005		$	82,294
Net income	$	217,557		$	188,914		$	70,618		$	161,953		$	140,203		$	153,526
Net income attributable to The Babcock & Wilcox Company	$	227,695		$	199,052		$	78,319		$	169,654		$	139,939		$	153,262
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	1.92		$	1.68		$	0.67		$	1.44		$	1.20		$	1.32
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	1.91		$	1.67		$	0.66		$	1.43		$	1.19		$	1.30
Consolidated and Combined Statements of Comprehensive Income:
Unrecognized losses arising during the period	$	(434	)	$	(21,486	)	$	(1,205	)	$	(140,436	)	$	(551	)	$	(62,059	)
Amortization of losses included in net income	$	2,281		$	51,976		$	2,487		$	50,382		$	2,386		$	50,571
Consolidated Balances Sheets:
Capital in excess of par value	$	713,257		$	1,143,275		$	676,952		$	1,106,971
Retained earnings	$	349,063		$	455,855		$	130,890		$	266,325
Accumulated other comprehensive income (loss)	$	32,728		$	(504,082	)	$	26,826		$	(538,628	)
Consolidated and Combined Statements of Cash Flows:
Net income	$	217,557		$	188,914		$	70,618		$	161,953		$	140,203		$	153,526
Provision for (benefit from) deferred taxes	$	43,038		$	25,672		$	(19,200	)	$	29,902		$	31,168		$	33,457
Recognition of losses and prior service cost for pension and postretirement plans	$	35,480		$	78,050		$	219,508		$	79,070		$	95,547		$	79,935

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Basis Of Presentation And Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2012

Contracts In Progress And Advance Billings

The following represent the components of our contracts in progress and advance billings on contracts included in our consolidated balance sheets:

	December 31,
	2012			2011
	(In thousands)
Included in Contracts in Progress:
Costs incurred less costs of revenue recognized	$	135,972		$	135,513
Revenues recognized less billings to customers		180,546			179,773
Contracts In Progress	$	316,518		$	315,286
Included In Advance Billings on Contracts:
Billings to customers less revenues recognized	$	541,983		$	492,106
Costs incurred less costs of revenue recognized		(69,696	)		(53,353	)
Advance Billings on Contracts	$	472,287		$	438,753

Retainages On Contracts

The following amounts represent retainages on contracts:

	December 31,
	2012		2011
	(In thousands)
Retainages expected to be collected within one year	$	85,776	$	60,158
Retainages expected to be collected after one year		28,661		14,526
Total retainages	$	114,437	$	74,684

Accumulated Other Comprehensive Loss

The components of accumulated other comprehensive income included in stockholders’ equity are as follows:

	December 31,
	2012			2011
	(In thousands)
Currency translation adjustments	$	40,899		$	36,626
Net unrealized gain on investments		597			201
Net unrealized gain on derivative financial instruments		2,103			2,717
Unrecognized prior service cost on benefit obligations		(10,871	)		(12,718	)
Accumulated other comprehensive income	$	32,728		$	26,826

Changes In Carrying Amount Of Accrued Warranty Expense

The following summarizes the changes in the carrying amount of accrued warranty expense:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	97,209		$	109,588		$	115,055
Additions		20,972			21,267			31,660
Expirations and other changes		(24,766	)		(14,288	)		(28,032	)
Charges		(10,217	)		(19,035	)		(10,532	)
Translation and other		484			(323	)		1,437
Balance at end of period	$	83,682		$	97,209		$	109,588

Asset Retirement Obligations

The following table reflects our asset retirement obligations:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Balance at beginning of period	$	35,885	$	32,657		$	29,491
Costs incurred		—		(2,265	)		—
Additions/Adjustments		3,422		2,935			—
Accretion		3,059		2,558			3,166
Balance at end of period	$	42,366	$	35,885		$	32,657

Inventories

Inventories are summarized below:

	December 31,
	2012		2011
	(In thousands)
Raw Materials and Supplies	$	98,428	$	77,932
Work in Progress		7,956		6,889
Finished Goods		17,834		22,477
Total Inventories	$	124,218	$	107,298

Property, Plant And Equipment

Property, plant and equipment is stated at cost and is set forth below:

	December 31,
	2012		2011
	(In thousands)
Land	$	11,875	$	11,656
Buildings		241,281		224,661
Machinery and equipment		776,678		710,666
Property under construction		69,206		70,439
		1,099,040		1,017,422
Less accumulated depreciation		652,019		595,131
Net Property, Plant and Equipment	$	447,021	$	422,291

Changes In Carrying Amount Of Goodwill

The following summarizes the changes in the carrying amount of goodwill:

	Power Generation		Nuclear Operations			Technical Services		Nuclear Energy		Total
	(In thousands)
Balance at December 31, 2010	$	88,042	$	122,407		$	45,000	$	13,975	$	269,424
Acquisition of Loibl (Note 2)		11,015		—			—		—		11,015
Foreign currency translation adjustments and other		45		(4,304	)		—		—		(4,259	)
Balance at December 31, 2011	$	99,102	$	118,103		$	45,000	$	13,975	$	276,180
Purchase price adjustment for acquisition of Loibl (Note 2)		3,727		—			—		—		3,727
Foreign currency translation adjustments and other		873		—			—		—		873
Balance at December 31, 2012	$	103,702	$	118,103		$	45,000	$	13,975	$	280,780

Schedule Of Intangible Assets

Other assets include the following intangible assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Amortized intangible assets:
Gross cost:
Customer relationships	$	36,644		$	40,051		$	37,167
Acquired backlog		2,979			22,435			19,335
Tradename		11,945			15,169			12,291
Unpatented technology		6,422			6,402			5,902
Patented technology		6,961			6,961			6,625
All other		7,912			7,901			11,935
Total	$	72,863		$	98,919		$	93,255
Accumulated amortization:
Customer relationships	$	(11,173	)	$	(8,618	)	$	(6,026	)
Acquired backlog		(1,457	)		(17,040	)		(12,701	)
Tradename		(6,422	)		(6,509	)		(4,260	)
Unpatented technology		(2,682	)		(2,033	)		(1,407	)
Patented technology		(4,235	)		(3,219	)		(2,096	)
All other		(4,343	)		(3,594	)		(6,296	)
Total	$	(30,312	)	$	(41,013	)	$	(32,786	)
Net amortized intangible assets	$	42,551		$	57,906		$	60,469
Unamortized intangible assets:
NRC category 1 license	$	43,830		$	43,830		$	43,830
Trademarks and trade names		1,305			1,305			1,305
Total unamortized intangible assets	$	45,135		$	45,135		$	45,135

Changes In Carrying Amount Of Intangible Assets

The following summarizes the changes in the carrying amount of intangible assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	103,041		$	105,604		$	103,379
Business acquisitions & adjustments		(1,746	)		9,100			14,280
Amortization expense		(11,010	)		(11,545	)		(11,679	)
Impairment charge		(3,216	)		—			—
Foreign currency translation adjustments and other		617			(118	)		(376	)
Balance at end of period	$	87,686		$	103,041		$	105,604

Estimated Amortization Expense

The estimated amortization expense for the next five fiscal years is as follows (in thousands):

Year Ending December 31,	Amount
2013	$	8,023
2014	$	5,494
2015	$	4,292
2016	$	4,215
2017	$	3,944

Changes In Carrying Amount Of Other Non-Current Assets

The following summarizes the changes in the carrying amount of these assets:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	5,723		$	8,102		$	1,898
Additions		4,902			82			9,994
Interest expense – debt issuance costs		(2,157	)		(2,461	)		(3,790	)
Balance at end of period	$	8,468		$	5,723		$	8,102

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Business Acquisitions And Investments (Tables)

12 Months Ended

Dec. 31, 2012

Loibl [Member]

Components Of Intangible Assets

The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Customer relationships	$	3,200	8 years
Backlog	$	3,100	2 years
Tradename	$	800	5 years
Unpatented technology	$	500	12 years

Ge Energy Businesses [Member]

Components Of Intangible Assets

The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Customer relationships	$	3,700	10 years
Patented technology	$	1,000	10 years
Backlog	$	400	1.5 years
Tradename	$	400	10 years

Gotaverken Miljo AB [Member]

Components Of Intangible Assets

The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Patented technology	$	2,460	15 years
Customer relationships	$	2,120	12 years
Tradenames and trademarks	$	1,160	20 years
Backlog	$	610	0.5 years

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Condensed Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 217,557	$ 70,618	$ 140,203
Non-cash items included in net income:
Depreciation and amortization	69,697	73,003	71,633
Income of investees, net of dividends	(15,115)	(20,854)	(20,449)
Losses (gains) on asset disposals and impairments - net	1,419	(3,087)	38
Impairment of USEC investment	27,000
In-kind research and development costs	17,942	16,584
Provision for ((benefit from) deferred taxes	43,038	(19,200)	31,168
Recognition of losses and prior service cost for pension and postretirement plans	35,480	219,508	95,547
Stock-based compensation expense	18,009	17,927	16,308
Excess tax benefits from stock-based compensation	(1,571)	(4,083)	(5,276)
Changes in assets and liabilities, net of effects from acquisitions:
Accounts receivable	(52,034)	(26,887)	101,260
Accounts payable	30,391	48,246	19,882
Net contracts in progress and advance billings	32,527	(28,746)	(153,933)
Income taxes	5,522	31,961	9,239
Accrued and other current liabilities	(30,553)	(23,106)	(9,761)
Pension liability and accrued postretirement and employee benefits	(168,004)	(144,802)	(85,371)
Other	(46,378)	(33,491)	(18,082)
NET CASH PROVIDED BY OPERATING ACTIVITIES	184,927	173,591	192,406
CASH FLOWS FROM INVESTING ACTIVITIES:
Decrease (increase) in restricted cash and cash equivalents	229	(48,923)	3,038
Purchases of property, plant and equipment	(86,635)	(63,874)	(63,649)
Acquisition of businesses, net of cash acquired	(318)	(11,907)	(29,962)
Purchases of available-for-sale securities	(268,929)	(145,198)	(135,135)
Sales and maturities of available-for-sale securities	247,649	147,288	134,276
Proceeds from asset disposals	580	6,468	753
Proceeds from sale of an unconsolidated affiliate	2,091
Investments, net of return of capital, in equity and cost method investees	(6,064)	(38,176)	(42,912)
Decrease in note receivable from affiliate			43,277
NET CASH USED IN INVESTING ACTIVITIES	(111,397)	(154,322)	(90,314)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payment of short-term borrowings and long-term debt	(4,643)	(1,782)	(29,914)
Payment of debt issuance costs	(4,902)	(82)	(9,994)
Increase in short-term borrowing	3,815	1,254	25,000
Repurchase of common shares	(96,774)
Dividends paid to common shareholders	(9,485)
Dividend paid to McDermott International, Inc.			(100,000)
Capital contribution from McDermott International, Inc.			12,501
Distribution to McDermott International, Inc.			(43,334)
(Decrease) Increase in notes payable to affiliates			(43,386)
Exercise of stock options	2,926	4,463	211
Excess tax benefits from stock-based compensation	1,571	4,083	5,276
Other	(514)	(401)	(93)
NET CASH (USED IN) PROVIDED BY FINANCING ACTIVITIES	(108,006)	7,535	(183,733)
EFFECTS OF EXCHANGE RATE CHANGES ON CASH	2,814	(2,737)	3,315
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS	(31,662)	24,067	(78,326)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	415,209	391,142	469,468
CASH AND CASH EQUIVALENTS AT END OF PERIOD	383,547	415,209	391,142
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Interest (net of amount capitalized)	3,842	4,525	3,746
Income taxes (net of refunds)	$ 83,062	$ 33,505	$ 27,227

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Equity Method Investments (Tables)

12 Months Ended

Dec. 31, 2012

Summary Of Combined Balance Sheet Information

Summarized below is combined balance sheet and income statement information for investments accounted for under the equity method:

	December 31,
	2012		2011
	(In thousands)
Current assets	$	835,997	$	855,962
Noncurrent assets		271,233		211,920
Total Assets	$	1,107,230	$	1,067,882
Current liabilities	$	616,786	$	594,883
Noncurrent liabilities		89,285		112,936
Owners’ equity		401,159		360,063
Total Liabilities and Owners’ Equity	$	1,107,230	$	1,067,882

Summary Of Combined Income Statement Information

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
Revenues	$	2,758,159	$	2,669,923	$	2,283,256
Gross profit	$	210,425	$	271,920	$	258,598
Income before provision for income taxes	$	146,911	$	185,859	$	182,482
Provision for income taxes		9,000		14,258		21,230
Net Income	$	137,911	$	171,601	$	161,252

Reconciliation Of Net Income To Equity In Income

Reconciliation of net income per combined income statement information of our investees to equity in income of investees per our consolidated and combined statements of income is as follows:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Equity income based on stated ownership percentages	$	66,064	$	81,971		$	77,882
All other adjustments due to amortization of basis differences, timing of GAAP adjustments and other adjustments		645		(3,316	)		(3,800	)
Equity in income of investees	$	66,709	$	78,655		$	74,082

Schedule Of Transactions With Unconsolidated Affiliates

Our transactions with unconsolidated affiliates were as follows:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
Sales to	$	42,538	$	49,400	$	45,321
Purchases from	$	1,814	$	980	$	4,693
Dividends received	$	51,594	$	57,801	$	53,633
Capital contributions, net of returns	$	6,289	$	38,176	$	5,412

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Pension Plans And Postretirement Benefits (Target Allocation By Asset Class) (Detail)	12 Months Ended
	Dec. 31, 2012
Domestic Plans [Member] | Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation by asset class	55.00%
Domestic Plans [Member] | Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation by asset class	45.00%
Canadian Plans [Member] | Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation by asset class	4500.00%
Canadian Plans [Member] | U. S. Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation by asset class	1700.00%
Canadian Plans [Member] | Global Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation by asset class	3800.00%
Diamond UK Plan [Member] | Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation by asset class	4500.00%
Diamond UK Plan [Member] | U. S. Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation by asset class	900.00%
Diamond UK Plan [Member] | Global Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocation by asset class	4600.00%

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Segment Reporting (Schedule of Property, Plant and Equipment, Net by Geographical Area) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Revenues from External Customers and Long-Lived Assets [Line Items]
Net Property, Plant And Equipment	$ 447,021	$ 422,291	$ 418,312
United States [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Net Property, Plant And Equipment	363,447	348,498	345,848
Canada [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Net Property, Plant And Equipment	45,402	41,868	41,959
United Kingdom [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Net Property, Plant And Equipment	9,714	9,758	10,401
Denmark [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Net Property, Plant And Equipment	8,565	8,813	8,395
Mexico [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Net Property, Plant And Equipment	8,302	7,024	6,299
Other Countries [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Net Property, Plant And Equipment	$ 11,591	$ 6,330	$ 5,410

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Fair Values Of Financial Instruments (Tables)

12 Months Ended

Dec. 31, 2012

Summary Of Available-For-Sale Securities Measured At Fair Value

The following is a summary of our available-for-sale securities measured at fair value at December 31, 2012:

	12/31/12		Level 1		Level 2		Level 3
	(In thousands)
Mutual funds	$	3,637	$	—	$	3,637	$	—
U.S. Government and agency securities		21,446		21,446		—		—
Asset-backed securities and collateralized mortgage obligations		454		—		454		—
Commercial paper		67,322		—		67,322		—
Total	$	92,859	$	21,446	$	71,413	$	—

The following is a summary of our available-for-sale securities measured at fair value at December 31, 2011:

	12/31/11		Level 1		Level 2		Level 3
	(In thousands)
Mutual funds	$	3,312	$	—	$	3,312	$	—
U.S. Government and agency securities		51,322		51,322		—		—
Asset-backed securities and collateralized mortgage obligations		462		—		462		—
Commercial paper		17,484		—		17,484		—
Total	$	72,580	$	51,322	$	21,258	$	—

Summary Of Changes In Level 3 Instrument Measured On Recurring Basis

The following is a summary of the changes in our Level 3 instrument measured on a recurring basis for the years ended December 31, 2012 and 2011:

	Year ended December 31,
	2012			2011
	(In thousands)
Balance at beginning of period	$	877		$	3,296
Total realized and unrealized gains (losses):
Included in other income (expense)-net		(560	)		(2,419	)
Included in other comprehensive income		—			—
Purchases, issuances, and settlements		—			—
Principal repayments		—			—
Balance at end of period	$	317		$	877

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Basis Of Presentation And Significant Accounting Policies (Changes In Carrying Amount Of Goodwill) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012 Loibl [Member]	Dec. 31, 2012 Power Generation [Member]	Dec. 31, 2011 Power Generation [Member]	Dec. 31, 2012 Power Generation [Member] Loibl [Member]	Dec. 31, 2011 Nuclear Operations [Member]	Dec. 31, 2012 Nuclear Operations [Member]	Dec. 31, 2012 Technical Services [Member]	Dec. 31, 2011 Technical Services [Member]	Dec. 31, 2010 Technical Services [Member]	Dec. 31, 2012 Nuclear Energy [Member]	Dec. 31, 2011 Nuclear Energy [Member]	Dec. 31, 2010 Nuclear Energy [Member]
Goodwill [Line Items]
Balance balance	$ 276,180	$ 269,424		$ 99,102	$ 88,042		$ 122,407	$ 118,103	$ 45,000	$ 45,000	$ 45,000	$ 13,975	$ 13,975	$ 13,975
Purchase price adjustment for acquisition of Loibl (Note 2)			3,727			3,727
Acquisition of Loibl (Note 2)		11,015			11,015
Foreign currency translation adjustments and other	873	(4,259)		873	45		(4,304)
Ending balance	$ 280,780	$ 276,180		$ 103,702	$ 99,102		$ 118,103	$ 118,103	$ 45,000	$ 45,000	$ 45,000	$ 13,975	$ 13,975	$ 13,975

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Long-Term Debt And Notes Payable (Components Of Long-Term Debt And Notes Payable) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Proforma Debt Instrument [Line Items]
Secured debt: Power Generation - various notes payable	$ 639	$ 831
Other	5	7
Long-term debt, gross total	644	838
Less: Amounts due within one year	214	205
Long-term debt	430	633
Short-term lines of credit	3,848	4,448
Current maturities of long-term debt	214	205
Total	$ 4,062	$ 4,653
Interest rate on short-term borrowing	6.60%	7.20%

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
ASSETS
Cash and cash equivalents	$ 383,547	$ 415,209
Restricted cash and cash equivalents	60,961	61,190
Investments	88,769	68,805
Accounts receivable - trade, net	364,960	305,832
Accounts receivable - other	61,682	77,505
Contracts in progress	316,518	315,286
Inventories	124,218	107,298
Deferred income taxes	78,573	102,022
Other current assets	41,858	33,929
Total Current Assets	1,521,086	1,487,076
Property, Plant and Equipment	1,099,040	1,017,422
Less accumulated depreciation	652,019	595,131
Net Property, Plant and Equipment	447,021	422,291
Investments	4,090	3,775
Goodwill	280,780	276,180
Deferred Income Taxes	227,215	241,739
Investments in Unconsolidated Affiliates	186,354	163,568
Other Assets	173,809	194,482
TOTAL	2,840,355	2,789,111
LIABILITIES AND STOCKHOLDERS' EQUITY
Notes payable and current maturities of long-term debt	4,062	4,653
Accounts payable	264,798	237,494
Accrued employee benefits	186,495	303,803
Accrued liabilities - other	57,991	71,079
Advance billings on contracts	472,287	438,753
Accrued warranty expense	83,682	97,209
Income taxes payable	9,973	1,816
Total Current Liabilities	1,079,288	1,154,807
Long-Term Debt	430	633
Accumulated Postretirement Benefit Obligation	71,208	80,663
Environmental Liabilities	46,497	44,069
Pension Liability	579,165	586,045
Other Liabilities	60,851	87,921
Commitments and Contingencies (Note 10)
Stockholders' Equity:
Common stock, par value $0.01 per share, authorized 325,000,000 shares; issued 119,608,026 and 118,458,911 shares at December 31, 2012 and December 31, 2011, respectively	1,196	1,185
Preferred stock, par value $0.01 per share, authorized 75,000,000 shares; no shares issued
Capital in excess of par value	713,257	676,952
Retained earnings	349,063	130,890
Treasury stock at cost, 4,372,143 and 351,876 shares at December 31, 2012 and December 31, 2011, respectively	(109,809)	(10,059)
Accumulated other comprehensive income	32,728	26,826
Stockholders' Equity - The Babcock & Wilcox Company	986,435	825,794
Noncontrolling interest	16,481	9,179
Total Stockholders' Equity	1,002,916	834,973
TOTAL	$ 2,840,355	$ 2,789,111

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Basis Of Presentation And Significant Accounting Policies (Narrative) (Detail) (USD $)	1 Months Ended	3 Months Ended		12 Months Ended
	Jul. 30, 2010	Sep. 30, 2011	Jun. 30, 2011	Dec. 31, 2012 Facility Segment Company	Dec. 31, 2011	Dec. 31, 2010
Basis Of Presentation And Significant Accounting Policies [Line Items]
Number of companies combined and contributed				2
Percentage of outstanding common stock distributed	100.00%
Common stock split	One share of B&W common stock for every two shares of MII common stock
Number of business segments				4
Common stock distributed to MII shareholders to complete spin-off	116,225,732
Net foreign currency transaction losses included in other expense				$ 600,000	$ 1,900,000	$ 6,500,000
Revenue recognition, percentage of contract completion				70.00%
Additional costs related to changes in estimates and scheduling issues		3,100,000	26,000,000	16,900,000	61,800,000
Potential liquidated damages under contract				6,000,000
Long-term retainages, anticipated collection in 2014				23,100,000
Long-term retainages, anticipated collection in 2015				2,900,000
Long-term retainages, anticipated collection in 2016				2,700,000
Number of facilities with U.S. Government decommissioning costs obligation				2
Research and development activities				173,900,000	163,000,000	102,100,000
Research and development activities, paid by customers				53,400,000	56,600,000	32,900,000
Minimum tax benefit likelihood of being realized upon settlement				50.00%
Percentage of total inventories using LIFO method				17.00%	19.00%
LIFO reserve				7,500,000	7,100,000
Depreciation expense				59,400,000	61,800,000	61,100,000
Impairment charges recognized				(3,216,000)
Interest expense				4,900,000	6,100,000	14,800,000
Capitalized interest expense				1,200,000	1,600,000	1,900,000
Restricted cash and cash equivalents				63,900,000
Reserves for self-insurance				42,800,000	43,600,000
Restricted Foreign Cash [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Restricted cash and cash equivalents				8,000,000
Cash Held For Future Decommissioning Of Facilities [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Restricted cash and cash equivalents				2,900,000
Cash Held To Meet Reinsurance Reserve Requirements [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Restricted cash and cash equivalents				51,900,000
Money Market Funds [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Restricted cash and cash equivalents				1,100,000
Nuclear Energy [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Additional costs related to changes in estimates and scheduling issues					50,700,000
Nuclear Operations [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Additional costs related to changes in estimates and scheduling issues					11,100,000
Recognition of Revenues from Settlement				18,400,000
Generation mPower LLC [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Research and development activities				$ 17,900,000	$ 16,600,000
Minimum [Member] | Buildings [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Estimated economic useful life				8 years
Minimum [Member] | Machinery and equipment [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Estimated economic useful life				2 years
Maximum [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Investment ownership in percentage				20.00%
Maximum [Member] | Buildings [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Estimated economic useful life				40 years
Maximum [Member] | Machinery and equipment [Member]
Basis Of Presentation And Significant Accounting Policies [Line Items]
Estimated economic useful life				28 years

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StockBasedCompensation - Schedule of Nonvested Cash Settled Restricted Stock Units (Detail) (Cash Settled Restricted Stock Unit [Member], USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012
Cash Settled Restricted Stock Unit [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested at beginning of period, Number of Shares
Granted, Number of Units	19
Vested, Number of Units
Cancelled/forfeited, Number of Units	(5)
Nonvested at end of period, Number of Shares	14
Nonvested at end of period, Weighted-Average Fair Value	$ 26.20

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Segment Reporting (Schedule of Revenues by Geographical Area) (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues	$ 865,296	$ 807,586	$ 852,585	$ 765,892	$ 800,789	$ 707,622	$ 752,352	$ 691,277	$ 3,291,359	[1],[2]	$ 2,952,040	[1],[2]	$ 2,688,811	[1],[2]
United States [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									2,615,387	[1]	2,340,299	[1]	2,133,924	[1]
Canada [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									288,246	[1]	238,663	[1]	252,089	[1]
Sweden [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									101,688	[1]	94,337	[1]	48,632	[1]
China [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									45,830	[1]	48,153	[1]	48,285	[1]
Germany [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									34,364	[1]	8,222	[1]	3,464	[1]
Argentina [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									23,529	[1]	21,016	[1]	4,374	[1]
Denmark [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									18,504	[1]	12,310	[1]	15,040	[1]
Finland [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									17,143	[1]	20,723	[1]	4,040	[1]
Korea [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									14,461	[1]	6,272	[1]	9,114	[1]
India [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									13,306	[1]	8,891	[1]	16,277	[1]
Chile [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									11,582	[1]	6,811	[1]	2,870	[1]
Norway [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									9,939	[1]	29,844	[1]	33,353	[1]
Italy [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									8,477	[1]	6,516	[1]	11,361	[1]
Saudi Arabia [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									7,973	[1]	3,307	[1]	1,689	[1]
Indonesia [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									7,828	[1]	4,642	[1]	6,048	[1]
United Kingdom [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									6,653	[1]	6,150	[1]	6,791	[1]
Japan [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									6,497	[1]	8,716	[1]	8,797	[1]
Bulgaria [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									2,620	[1]	14,149	[1]	2,144	[1]
Brazil [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									2,585	[1]	4,671	[1]	2,957	[1]
France [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									2,384	[1]	3,433	[1]	5,373	[1]
Ireland [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									2,189	[1]	14,769	[1]	26,574	[1]
Other Countries [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues									$ 50,174	[1]	$ 50,146	[1]	$ 45,615	[1]

[1] We allocate geographic revenues based on the location of the customer's operations.

[2] Segment revenues are net of the following intersegment transfers and other adjustments:

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Condensed Consolidated Statement Of Stockholders Equity (USD $) In Thousands, except Share data	Total	Common Stock	Capital In Excess of Par Value	Retained Earnings	Accumulated Other Comprehensive Loss	Treasury Stock	Parent Equity	Non-Controlling Interest
Balance at Dec. 31, 2009	$ 120,706				$ 8,216		$ 111,987	$ 503
Balance, Shares at Dec. 31, 2009		0
Net income	140,203			52,571			87,368	264
Amortization of benefit plan costs	2,386				2,386
Unrealized loss on benefit obligations	(551)				(551)
Unrealized gain on investments	645				645
Translation adjustments	7,561				7,582			(21)
Unrealized gain on derivatives	7,697				7,697
Transfer of pension to Parent	1,544				1,544
Dividend paid	(100,000)						(100,000)
Net transactions with Parent	520,166				(3,400)		523,566
Reclassification of Parent equity to capital in excess of par value			622,921				(622,921)
Issuance of common stock at spin-off		1,162	(1,162)
Issuance of common stock at spin-off, Shares		116,225,732
Exercise of stock options	3,428	1	3,427
Exercise of stock options, Shares		86,004
Contributions to thrift plan	5,173	2	5,171
Contributions to thrift plan, Shares		218,699
Shares placed in treasury	(2,397)					(2,397)
Stock-based compensation charges	7,044	5	7,039
Stock-based compensation charges, Shares		433,229
Distributions to noncontrolling interests	(80)							(80)
Balance at Dec. 31, 2010	713,525	1,170	637,396	52,571	24,119	(2,397)		666
Balance, Shares at Dec. 31, 2010		116,963,664
Net income	70,618			78,319				(7,701)
Amortization of benefit plan costs	2,487				2,487
Unrealized loss on benefit obligations	(1,205)				(1,205)
Unrealized gain on investments	(69)				(69)
Translation adjustments	747				716			31
Unrealized gain on derivatives	778				778
Exercise of stock options	8,546	4	8,542
Exercise of stock options, Shares		379,706
Contributions to thrift plan	13,098	5	13,093
Contributions to thrift plan, Shares		510,510
Shares placed in treasury	(7,662)					(7,662)
Stock-based compensation charges	17,927	6	17,921
Stock-based compensation charges, Shares		605,031
Contribution of in-kind services	16,584							16,584
Distributions to noncontrolling interests	(401)							(401)
Balance at Dec. 31, 2011	834,973	1,185	676,952	130,890	26,826	(10,059)		9,179
Balance, Shares at Dec. 31, 2011	118,458,911	118,458,911
Net income	217,557			227,695				(10,138)
Amortization of benefit plan costs	2,281				2,281
Unrealized loss on benefit obligations	(434)				(434)
Unrealized gain on investments	396				396
Translation adjustments	4,284				4,273			11
Unrealized gain on derivatives	(614)				(614)
Dividend paid	(9,522)			(9,522)
Exercise of stock options	4,514	3	4,511
Exercise of stock options, Shares		261,784
Contributions to thrift plan	13,793	5	13,788
Contributions to thrift plan, Shares		549,121
Shares placed in treasury	(99,750)					(99,750)
Stock-based compensation charges	18,009	3	18,006
Stock-based compensation charges, Shares		338,210
Contribution of in-kind services	17,942							17,942
Distributions to noncontrolling interests	(513)							(513)
Balance at Dec. 31, 2012	$ 1,002,916	$ 1,196	$ 713,257	$ 349,063	$ 32,728	$ (109,809)		$ 16,481
Balance, Shares at Dec. 31, 2012	119,608,026	119,608,026

XML

Stock-Based Compensation - Schedule of Summarized Activity of Stock Appreciation (Detail) (Stock Appreciation Right [Member], USD $) Share data in Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012
Stock Appreciation Right [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding at end of period, Weighted-Average Remaining Contractual Term	6 years 6 months
Exercisable at end of period, Weighted-Average Remaining Contractual Term	0 years
Outstanding at beginning of period, Weighted-Average Exercise Price
Granted, Weighted-Average Exercise Price	$ 25.23
Exercised, Weighted-Average Exercise Price
Cancelled/expired/forfeited, Weighted-Average Exercise Price	$ 25.11
Outstanding at end of period, Weighted-Average Exercise Price	$ 25.27
Exercisable at end of period, Weighted-Average Exercise Price
Outstanding at beginning of period, Number of Shares
Granted, Number of Units	49
Exercised, Number of Shares
Cancelled/expired/forfeited, Number of Shares	(12)
Outstanding at end of period, Number of Shares	37
Exercisable at end of period, Number of Shares
Outstanding at end of period, Aggregate Intrinsic Value	$ 0.0
Exercisable at end of period, Aggregate Intrinsic Value

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Business Acquisitions and Investments (Components of Intangible Assets) (Detail) (USD $) In Thousands, unless otherwise specified		1 Months Ended					1 Months Ended					1 Months Ended
	Nov. 30, 2011 Anlagenbau und Fordertechnik Arthur Loibl GmbH [Member]	Nov. 30, 2011 Anlagenbau und Fordertechnik Arthur Loibl GmbH [Member] Customer Relationships [Member]	Nov. 30, 2011 Anlagenbau und Fordertechnik Arthur Loibl GmbH [Member] Backlog [Member]	Nov. 30, 2011 Anlagenbau und Fordertechnik Arthur Loibl GmbH [Member] Tradename [Member]	Nov. 30, 2011 Anlagenbau und Fordertechnik Arthur Loibl GmbH [Member] Unpatented Technology [Member]	Apr. 02, 2010 Ge Energy Businesses [Member]	Apr. 02, 2010 Ge Energy Businesses [Member] Customer Relationships [Member]	Apr. 02, 2010 Ge Energy Businesses [Member] Backlog [Member]	Apr. 02, 2010 Ge Energy Businesses [Member] Tradename [Member]	Apr. 02, 2010 Ge Energy Businesses [Member] Patented Technology [Member]	Jan. 31, 2010 Gotaverken Miljo AB [Member]	Jan. 31, 2010 Gotaverken Miljo AB [Member] Customer Relationships [Member]	Jan. 31, 2010 Gotaverken Miljo AB [Member] Backlog [Member]	Jan. 31, 2010 Gotaverken Miljo AB [Member] Patented Technology [Member]	Jan. 31, 2010 Gotaverken Miljo AB [Member] Tradenames And Trademarks [Member]	Jan. 31, 2010 Gotaverken Miljo AB [Member] Customer Relationship [Member]
Business Acquisition [Line Items]
Intangible assets, Amount	$ 7,600	$ 3,200	$ 3,100	$ 800	$ 500	$ 5,500	$ 3,700	$ 400	$ 400	$ 1,000	$ 6,400		$ 610	$ 2,460	$ 1,160	$ 2,120
Intangible Assets, Amortization Period, years		8 years	2 years	5 years	12 years		10 years	1 year 6 months	10 years	10 years		12 years	6 months	15 years	20 years

XML

Related Party Transactions (Narrative) (Detail) (USD $)	1 Months Ended	12 Months Ended	1 Months Ended	7 Months Ended	9 Months Ended	12 Months Ended
	Jan. 31, 2010	Dec. 31, 2010	Jun. 30, 2010 McDermott International, Inc. [Member]	Jul. 31, 2010 McDermott International, Inc. [Member]	Sep. 30, 2010 McDermott International, Inc. [Member]	Dec. 31, 2010 McDermott International, Inc. [Member]
Related Party Transaction [Line Items]
Corporate and general and administrative expenses allocated to parent				$ 20,000,000
Interest expense attributable to intercompany loan					8,700,000
Cumulative reduction in parent equity	554,800,000
Dividend paid to parent		(100,000,000)	100,000,000
Increase of capital in excess of par value						523,600,000
Forgiveness of intercompany balances owed to parent						178,000,000
Noncash settlement of note payable to parent company's affiliate						277,800,000
Distribution of net assets to parent						20,700,000
Distribution of cash to parent		43,277,000
Cash received from parent in settlement of note receivable		43,300,000
(Decrease) increase in notes payable to affiliates		43,386,000
Capital contribution from McDermott International, Inc.		$ 12,501,000

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Pension Plans And Postretirement Benefits (Tables)

12 Months Ended

Dec. 31, 2012

Obligations And Funded Status

Obligations and Funded Status

	Pension Benefits Year Ended December 31,						Other Benefits Year Ended December 31,
	2012			2011			2012			2011
	(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of period	$	2,687,007		$	2,479,783		$	122,460		$	125,692
Service cost		46,828			43,495			1,138			1,143
Interest cost		122,605			134,927			5,124			5,805
Plan participants’ contributions		300			318			115			116
Curtailments		(94,642	)		—			—			—
Amendments		2,996			2,055			(1,302	)		(1,351	)
Settlements		(57,430	)		(13,625	)		—			—
Actuarial loss (gain)		198,935			181,517			(2,153	)		1,491
Foreign currency exchange rate changes		6,793			(5,633	)		220			(211	)
Benefits paid		(133,402	)		(135,830	)		(9,346	)		(10,225	)
Benefit obligation at end of period	$	2,779,990		$	2,687,007		$	116,256		$	122,460
Change in plan assets:
Fair value of plan assets at beginning of period	$	1,917,850		$	1,782,048		$	33,558		$	33,389
Actual return on plan assets		207,728			115,787			2,233			723
Plan participants’ contributions		300			318			115			116
Company contributions		187,284			174,639			10,764			9,555
Settlements		(57,430	)		(13,625	)		—			—
Foreign currency exchange rate changes		5,364			(5,487	)		—			—
Benefits paid		(133,402	)		(135,830	)		(9,346	)		(10,225	)
Fair value of plan assets at the end of period		2,127,694			1,917,850			37,324			33,558
Funded status	$	(652,296	)	$	(769,157	)	$	(78,932	)	$	(88,902	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(75,119	)	$	(185,832	)	$	(7,724	)	$	(8,239	)
Accumulated postretirement benefit obligation		—			—			(71,208	)		(80,663	)
Pension liability		(577,177	)		(583,337	)		—			—
Prepaid pension		—			12			—			—
Accrued benefit liability, net	$	(652,296	)	$	(769,157	)	$	(78,932	)	$	(88,902	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	18,327		$	19,949		$	(2,523	)	$	(1,360	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	2,779,990		$	2,686,796			N/A			N/A
Accumulated benefit obligation	$	2,723.930		$	2,515,868		$	116,256		$	122,460
Fair value of plan assets	$	2,127,694		$	1,917,626		$	37,324		$	33,558
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	211			N/A			N/A
Accumulated benefit obligation	$	—		$	211		$	—		$	—
Fair value of plan assets	$	—		$	224		$	—		$	—

Components Of Net Periodic Benefit Cost

	Pension Benefits Year Ended December 31,									Other Benefits Year Ended December 31,
	2012			2011			2010			2012			2011			2010
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	46,828		$	43,495		$	39,176		$	1,138		$	1,143		$	1,069
Interest cost		122,605			134,927			142,092			5,124			5,805			7,284
Expected return on plan assets		(136,913	)		(148,347	)		(136,364	)		(1,930	)		(1,919	)		(1,744	)
Amortization of prior service cost		3,579			3,721			3,711			(139	)		33			28
Recognized net actuarial loss (gain)		34,496			212,802			106,805			(2,456	)		2,952			(14,997	)
Net periodic benefit cost (income)	$	70,595		$	246,598		$	155,420		$	1,737		$	8,014		$	(8,360	)

Additional Information

Additional Information

	Pension Benefits Year Ended December 31,						Other Benefits Year Ended December 31,
	2012			2011			2012		2011
	(In thousands)
Increase (decrease) in accumulated other comprehensive income due to actuarial losses—before taxes	$	(1,957	)	$	(3,258	)	$	1,302	$	1,616

Weighted Average Assumptions

Assumptions

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate		4.09	%		4.76	%		3.43	%		4.35	%
Rate of compensation increase		2.57	%		3.69	%		—			—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate		4.76	%		5.56	%		4.34	%		4.92	%
Expected return on plan assets		7.08	%		8.24	%		5.76	%		5.76	%
Rate of compensation increase		3.69	%		3.69	%		—			—

Assumed Health-Care Cost Trend Rates

	2012			2011
Assumed health-care cost trend rates at December 31
Health-care cost trend rate assumed for next year		8.50	%		8.00	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)		4.50	%		4.50	%
Year that the rate reaches ultimate trend rate		2021			2019

Effect Of One-Percentage-Point Change In Assumed Health-Care Cost Trend Rates

A one-percentage-point change in our assumed health-care cost trend rates would have the following effects:

	One-Percentage- Point Increase		One-Percentage- Point Decrease
	(In thousands)
Effect on total of service and interest cost	$	475	$	(401	)
Effect on postretirement benefit obligation	$	7,756	$	(6,456	)

Summary Of Total Investments Measured At Fair Value

The following is a summary of total investments for our plans measured at fair value at December 31, 2012:

	12/31/12		Level 1		Level 2		Level 3
	(In thousands)
Pension and Other Benefits:
Fixed Income	$	649,978	$	1,031	$	648,947	$	—
Equities		120,223		120,220		—		3
Commingled and Mutual Funds		791,195		9,084		782,111		—
U.S. Government Securities		425,709		425,709		—		—
Partnerships with Security Holdings		112,881		—		—		112,881
Real Estate		14,516		—		—		14,516
Cash and Accrued Items		50,516		46,785		3,731		—
Total Assets	$	2,165,018	$	602,829	$	1,434,789	$	127,400

The following is a summary of total investments for our plans measured at fair value at December 31, 2011:

	12/31/11		Level 1		Level 2		Level 3
	(In thousands)
Pension and Other Benefits:
Fixed Income	$	550,146	$	—	$	550,146	$	—
Equities		298,083		298,077		—		6
Commingled and Mutual Funds		546,776		8,250		538,526		—
U.S. Government Securities		313,458		313,458		—		—
Partnerships with Security Holdings		134,295		—		—		134,295
Real Estate		53,560		—		—		53,560
Cash and Accrued Items		55,090		54,970		120		—
Total Assets	$	1,951,408	$	674,755	$	1,088,792	$	187,861

Summary Of Changes In Plans' Level 3 Instruments Measured On Recurring Basis

The following is a summary of the changes in the Plans’ Level 3 instruments measured on a recurring basis for the years ended December 31, 2012 and 2011:

	Year ended December 31,
	2012			2011
	(In thousands)
Balance at beginning of period	$	187,861		$	207,244
Issuances and acquisitions		12,593			16,821
Dispositions		(74,329	)		(52,572	)
Realized gain		692			5,897
Unrealized gain		583			10,471
Balance at end of period	$	127,400		$	187,861

Cash Flows

Cash Flows

	Domestic Plans				Foreign Plans
	Pension Benefits		Other Benefits		Pension Benefits		Other Benefits
	(In thousands)
Expected employer contributions to trusts of defined benefit plans:
2013	$	52,000	$	2,082	$	20,040		N/A
Expected benefit payments:
2013		127,558		12,500		11,389		596
2014		133,785		11,768		12,075		621
2015		139,444		10,581		12,731		613
2016		144,617		9,470		13,671		598
2017		149,047		8,163		14,116		618
2018-2022		785,955		28,708		79,572		3,315

Summary of Contributions to Multiemployer Plans

The following table summarizes our contributions to multiemployer plans for the years covered by this report:

		Pension Protection										Expiration Date
		Act Zone		FIP/RP Status	Contributions							Of Collective
		Zone Status		Pending/	2012		2011		2010		Surcharge	Bargaining
Pension Fund	EIN/PIN	2012	2011	Implemented	(in millions)						Imposed	Agreement
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	18.9	$	25.9	$	12.4	No	Described Below
All Other						5.3		5.5		6.0
					$	24.2	$	31.4	$	18.4

Domestic Plans [Member]

Plan Asset Allocations By Asset Category

The following is a summary of the asset allocations for the Master Trust at December 31, 2012 and 2011 by asset category:

	2012			2011
Asset Category:
Commingled and Mutual Funds		34	%		25	%
Fixed Income (excluding U. S. Government Securities)		29	%		27	%
U.S. Government Securities		22	%		18	%
Equity Securities		6	%		17	%
Partnerships with Security Holdings		6	%		8	%
Real Estate		1	%		3	%
Other		2	%		2	%
Total		100	%		100	%

Target Allocation By Asset Class

The target allocation for 2013 for the domestic plans, by asset class, is as follows:

Asset Class:
Fixed Income	55	%
Equities	45	%

Foreign Plans [Member]

Plan Asset Allocations By Asset Category

The combined weighted average asset allocations of these plans at December 31, 2012 and 2011 by asset category were as follows:

	2012			2011
Asset Category:
Equity Securities and Commingled Mutual Funds		58	%		56	%
Fixed Income		40	%		41	%
Other		2	%		3	%
Total		100	%		100	%

Target Allocation By Asset Class

The target allocation for 2013 for the foreign plans, by asset class, is as follows:

	Canadian Plans			Diamond UK Plan
Asset Class:
U. S. Equity		17	%		9	%
Global Equity		38	%		46	%
Fixed Income		45	%		45	%

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Income Taxes (Reconciliation Of Unrecognized Tax Benefits) (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Reconciliation Of Unrecognized Tax Benefits [Line Items]
Balance at beginning of period		$ 32,357	$ 36,342	$ 11,842
Increases based on tax positions taken in the current year		980	1,171	6,550
Increases based on tax positions taken in the prior years		65	3,269	343
Increases due to positions assumed at spin-off				24,181
Decreases based on tax positions taken in the prior years		(3,114)	(4,329)	(1,442)
Decreases due to settlements with tax authorities		(1,101)	(1,073)	(5,132)
Decreases due to lapse of applicable statute of limitation	(25,300)	(24,700)	(3,023)
Balance at end of period	$ 4,487	$ 4,487	$ 32,357	$ 36,342

XML

Investments

12 Months Ended

Dec. 31, 2012

Investments

NOTE 14 – INVESTMENTS

The following is a summary of our available-for-sale securities at December 31, 2012:

	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Estimated Fair  Value
	(In thousands)
U.S. Government and agency securities	$	21,436	$	10	$	—		$	21,446
Mutual funds		2,958		679		—			3,637
Asset-backed securities and collateralized mortgage obligations		554		2		(102	)		454
Commercial paper		67,313		9		—			67,322
Total	$	92,261	$	700	$	(102	)	$	92,859

The following is a summary of our available-for-sale securities at December 31, 2011:

	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Estimated Fair  Value
	(In thousands)
U.S. Government and agency securities	$	51,308	$	14	$	—		$	51,322
Mutual funds		2,957		355		—			3,312
Asset-backed securities and collateralized mortgage obligations		633		—		(171	)		462
Commercial paper		17,481		4		(1	)		17,484
Total	$	72,379	$	373	$	(172	)	$	72,580

Proceeds, gross realized gains and gross realized losses on sales of available-for-sale securities were as follows:

	Proceeds		Gross Realized  Gains		Gross Realized  Losses
	(In thousands)
Year Ended December 31, 2012	$	247,649	$	35	$	—
Year Ended December 31, 2011	$	147,288	$	—	$	5
Year Ended December 31, 2010	$	134,276	$	—	$	122

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Stock-Based Compensation (Tables)

12 Months Ended

Dec. 31, 2012

Schedule of Assumptions Used to Calculate Fair Value of Option Grant

	Year Ended December 31, 2010
Risk-free interest rate		2.18	%
Expected volatility		0.55
Expected life of the option in years		4.79
Expected dividend yield		0	%

Summarized Activity of Stock Options

	Number of Shares			Weighted- Average Exercise Price		Weighted- Average Remaining Contractual Term		Aggregate Intrinsic Value (in  millions)
Outstanding at beginning of period		1,154		$	22.68
Granted		711			25.96
Exercised		(262	)		11.24
Cancelled/expired/forfeited		(171	)		29.05
Outstanding at end of period		1,432		$	25.65		5.2 Years	$	4.2
Exercisable at end of period		536		$	22.31		4.1 Years	$	3.5

Schedule of Summarized Activity of Stock Appreciation

	Number of Units			Weighted- Average Exercise Price		Weighted- Average Remaining Contractual Term		Aggregate Intrinsic Value (in  millions)
Outstanding at beginning of period		—		$	—
Granted		49			25.23
Exercised		—			—
Cancelled/expired/forfeited		(12	)		25.11
Outstanding at end of period		37		$	25.27		6.5 Years	$	0.0
Exercisable at end of period		—		$	—		—	$	—

Cash Settled Performance Shares [Member]

Schedule of Cash Settled Performance Units

	Number of Units			Weighted- Average Fair  Value
Nonvested at beginning of period		—
Granted		40
Vested		—
Cancelled/forfeited		(10	)
Nonvested at end of period		30		$	26.20

Cash Settled Restricted Stock Units [Member]

Schedule of Cash Settled Performance Units

	Number of Units			Weighted- Average Fair  Value
Nonvested at beginning of period		—
Granted		40
Vested		—
Cancelled/forfeited		(10	)
Nonvested at end of period		30		$	26.20

B&W Stock Options [Member]

Schedule of Assumptions Used to Calculate Fair Value of Option Grant

	Year Ended December 31,
	2012			2011			2010
Risk-free interest rate		0.65	%		1.52	%		1.28	%
Expected volatility		.36			.46			.61
Expected life of the option in years		3.98			3.75			4.08
Expected dividend yield		0	%		0	%		0	%

Schedule of Cash Settled Performance Units

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		13		$	20.58
Granted		—			—
Vested		(7	)		19.04
Cancelled/forfeited		—			—
Nonvested at end of period		6		$	22.39

B&W Cash-Based Performance and Restricted Stock Units [Member]

Schedule of Assumptions Used to Calculate Fair Value of Option Grant

	Year Ended December 31, 2010
Risk-free interest rate		2.18	%
Expected volatility		0.55
Expected life of the option in years		4.79
Expected dividend yield		0	%

Schedule of Cash Settled Performance Units

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		477		$	33.56
Granted		493			26.09
Vested		—			—
Cancelled/forfeited		(171	)		30.77
Nonvested at end of period		799		$	29.55

B&W Restricted Stock Units [Member]

Schedule of Cash Settled Performance Units

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		491		$	22.25
Granted		365			25.53
Vested		(357	)		19.31
Cancelled/forfeited		(78	)		27.69
Nonvested at end of period		421		$	26.58

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Commitments and Contingencies (Schedule of Future Minimum Payments for Operating Leases) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012
Future Minimum Payments Under Non Cancelable Operating Leases With Initial Terms Of One Year Or More [Line Items]
2013	$ 10,314
2014	9,168
2015	10,751
2016	4,761
2017	4,207
Thereafter	$ 4,734

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Fair Values Of Financial Instruments

12 Months Ended

Dec. 31, 2012

Fair Values Of Financial Instruments

NOTE 16 – FAIR VALUES OF FINANCIAL INSTRUMENTS

FASB Topic Fair Value Measurements and Disclosures defines fair value as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. This topic also sets forth the disclosure requirements regarding fair value and establishes a hierarchy for valuation inputs that emphasizes the use of observable inputs when measuring fair value. A financial instrument’s categorization within the fair value hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The fair value hierarchy established by this topic is as follows:

• Level 1 – inputs are based upon quoted prices for identical instruments traded in active markets.

• Level 2 – inputs are based upon quoted prices for similar instruments in active markets, quoted prices for similar or identical instruments in inactive markets and model-based valuation techniques for which all significant assumptions are observable in the market or can be corroborated by observable market data for substantially the full term of the assets and liabilities.

• Level 3 – inputs are generally unobservable and typically reflect management’s estimates of assumptions that market participants would use in pricing the asset or liability. The fair values are therefore determined using model-based techniques that include option pricing models, discounted cash flow models and similar valuation techniques.

The following sections describe the valuation methodologies we use to measure the fair values of our available-for-sale securities, derivatives and nonrecurring fair value measurements.

Available-for-Sale-Securities

Investments other than derivatives primarily include U.S. Government and agency securities, money-market funds, mortgage-backed securities and corporate notes and bonds.

In general, and where applicable, we principally use a composite of observable prices and quoted prices in active markets for identical assets or liabilities to determine fair value. This pricing methodology applies to our Level 1 and 2 investments.

Our net unrealized gain/loss on investments is currently in an unrealized gain position totaling approximately $0.6 million at December 31, 2012. At December 31, 2011, we had an unrealized gain on our investments totaling approximately $0.2 million. Based on our analysis of these investments, we believe that none of our available-for-sale securities were other than temporarily impaired at December 31, 2012.

Fair Value Measurements

The following is a summary of our available-for-sale securities measured at fair value at December 31, 2012:

	12/31/12		Level 1		Level 2		Level 3
	(In thousands)
Mutual funds	$	3,637	$	—	$	3,637	$	—
U.S. Government and agency securities		21,446		21,446		—		—
Asset-backed securities and collateralized mortgage obligations		454		—		454		—
Commercial paper		67,322		—		67,322		—
Total	$	92,859	$	21,446	$	71,413	$	—

The following is a summary of our available-for-sale securities measured at fair value at December 31, 2011:

	12/31/11		Level 1		Level 2		Level 3
	(In thousands)
Mutual funds	$	3,312	$	—	$	3,312	$	—
U.S. Government and agency securities		51,322		51,322		—		—
Asset-backed securities and collateralized mortgage obligations		462		—		462		—
Commercial paper		17,484		—		17,484		—
Total	$	72,580	$	51,322	$	21,258	$	—

Derivatives

Level 2 derivative assets and liabilities currently consist of FX rate derivatives. Where applicable, the value of these derivative assets and liabilities is computed by discounting the projected future cash flow amounts to present value using market-based observable inputs, including FX forward and spot rates, interest rates and counterparty performance risk adjustments. At December 31, 2012, we had forward contracts outstanding to purchase or sell foreign currencies, primarily Canadian Dollars and Danish Kroner with a total notional amount of $170.3 million and a total fair value of $3.3 million.

Level 3 derivative assets include warrants to purchase common stock. The value of the warrants are computed using an option pricing model based on unobservable inputs such as a 40% stock price discount for inactive shares, and observable inputs, including interest rates and volatility. At December 31, 2012, the warrants had a fair value of $0.3 million.

Changes in Level 3 Instrument

The following is a summary of the changes in our Level 3 instrument measured on a recurring basis for the years ended December 31, 2012 and 2011:

	Year ended December 31,
	2012			2011
	(In thousands)
Balance at beginning of period	$	877		$	3,296
Total realized and unrealized gains (losses):
Included in other income (expense)-net		(560	)		(2,419	)
Included in other comprehensive income		—			—
Purchases, issuances, and settlements		—			—
Principal repayments		—			—
Balance at end of period	$	317		$	877

Nonrecurring Fair Value Measurements

As described in Note 2, we performed a fair value analysis of our USEC Preferred Stock investment in the third quarter of 2012 for impairment purposes resulting in a fair value determination of $19.1 million. Fair value was determined using a combination of an option pricing model and a probability of default methodology. The fair value has been classified as Level 3 of the fair value hierarchy. The fair value measurement includes unobservable inputs for estimated default recovery rates ranging from 30% to 50%.

Other Financial Instruments

We used the following methods and assumptions in estimating our fair value disclosures for our other financial instruments, as follows:

Cash and cash equivalents and restricted cash and cash equivalents. The carrying amounts that we have reported in the accompanying consolidated balance sheets for cash and cash equivalents approximate their fair values due to their highly liquid nature. The fair value has been classified as Level 1 of the fair value hierarchy.

Long- and short-term debt. We base the fair values of debt instruments on quoted market prices. Where quoted prices are not available, we base the fair values on the present value of future cash flows discounted at estimated borrowing rates for similar debt instruments or on estimated prices based on current yields for debt issues of similar quality and terms. The fair value of our debt instruments approximated their carrying value at December 31, 2012 and December 31, 2011. The fair value has been classified as Level 2 of the fair value hierarchy.

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Income Taxes (Income Before Provision For Income Taxes) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule Of Components Of Income Before Income Tax Expense Benefit [Line Items]
U.S.	$ 222,840	$ 39,417	$ 174,242
Other than U.S.	96,578	55,081	45,966
Income before provision for income taxes	$ 319,418	$ 94,498	$ 220,208

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Fair Values Of Financial Instruments (Summary Of Changes In Level 3 Instrument Measured On Recurring Basis) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Balance	$ 877	$ 3,296
Total realized and unrealized gains (losses):
Total realized and unrealized gains (losses), Included in other income (expense)	(560)	(2,419)
Total realized and unrealized gains (losses), Included in other comprehensive income
Purchases, issuances, and settlements
Principal repayments
Balance	$ 317	$ 877

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Condensed Consolidated Statement Of Stockholders Equity (Parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2012
Dividends declared, per share	$ 0.08

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Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2012	Dec. 31, 2011
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	325,000,000	325,000,000
Common stock, shares issued	119,608,026	118,458,911
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	75,000,000	75,000,000
Preferred stock, shares issued	0	0
Treasury stock at cost, shares	4,372,143	351,876

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Stock-Based Compensation

12 Months Ended

Dec. 31, 2012

Stock-Based Compensation

NOTE 9—STOCK-BASED COMPENSATION

2010 Long-Term Incentive Plan of The Babcock & Wilcox Company

We established the 2010 Long-Term Incentive Plan of The Babcock & Wilcox Company (the “Plan”). Members of the Board of Directors, executive officers, key employees and consultants are eligible to participate in the Plan. The Compensation Committee of the Board of Directors selects the participants for the Plan. The Plan provides for a number of forms of stock-based compensation, including incentive and non-qualified stock options, restricted stock, restricted stock units and performance shares and performance units, subject to satisfaction of specific performance goals. Shares subject to awards under the Plan that are cancelled, forfeited, terminated or expire unexercised, shall immediately become available for the granting of awards under this Plan. In addition, 10,000,000 shares were authorized for issuance through the Plan. Options to purchase shares are granted at not less than 100% of the fair market value closing price on the date of grant, become exercisable at such time or times as determined when granted and expire not more than seven years after the date of grant.

At December 31, 2012, we had awarded 4,610,485 shares under this plan, and had a total of 5,389,515 shares of our common stock available for future awards. In the event of a change in control of our company, the terms of the awards under the Plan contain provisions that may cause restrictions to lapse and accelerate the vesting of plan awards.

2012 Long-Term Incentive Plan of Babcock & Wilcox Technical Services Group, Inc.

In June 2012, we established the 2012 Long-Term Incentive Plan of Babcock & Wilcox Technical Services Group, Inc., a cash-settled plan for employees of certain subsidiaries and unconsolidated affiliates as selected by the plan committee. The cash-settled plan provides for a number of forms of stock-based compensation, including stock appreciation rights, restricted stock units and performance units, subject to satisfaction of specific performance goals. Stock appreciation rights are granted at not less than 100% of the fair market value closing price of a share of B&W common stock on the date of grant, become exercisable at such time or times as determined when granted and expire not more than seven years after the date of grant. Stock appreciation rights are cash settled for the excess of the market price of B&W common stock on the exercise date minus the exercise price. Restricted stock units and performance units are cash settled upon vesting as determined when granted. We will not issue any shares of B&W common stock under this plan, as all awards are cash settled.

In the event of a change in control of our company, the terms of the awards under the cash-settled plan contain provisions that may cause restrictions to lapse and accelerate the vesting of plan awards.

Total stock-based compensation expense for all of our plans recognized for the years ended December 31, 2012, 2011 and 2010 totaled $18.3 million, $17.9 million and $16.3 million, respectively, with associated tax benefit recognized for the years ended December 31, 2012, 2011 and 2010 totaling $6.9 million, $6.6 million and $6.0 million, respectively.

Prior to August 1, 2010, all of our stock-based compensation expense was attributable to our participation in MII legacy stock-based compensation plans. Expense recognized prior to August 1, 2010 was based on the fair value of MII’s stock-based compensation awards. For the five month period August 1, 2010 to December 31, 2010, stock-based compensation expense attributable to the Plan totaled $4.4 million, net of tax benefits totaling $2.6 million.

As of December 31, 2012, total unrecognized estimated compensation expense related to nonvested awards was $15.6 million, net of estimated tax benefits of $9.5 million. The total gross unrecognized estimated compensation expense of $25.1 million is expected to be recognized over a weighted-average period of 1.9 years.

B&W Stock Options

The fair value of each option grant was estimated at the date of grant using Black-Scholes, with the following weighted-average assumptions:

	Year Ended December 31,
	2012			2011			2010
Risk-free interest rate		0.65	%		1.52	%		1.28	%
Expected volatility		.36			.46			.61
Expected life of the option in years		3.98			3.75			4.08
Expected dividend yield		0	%		0	%		0	%

The risk-free interest rate is based on the implied yield on a U.S. Treasury zero-coupon issue with a remaining term equal to the expected life of the option. The expected volatility is based on implied volatility from publicly traded options on our common stock, historical volatility of the price of our common stock and other factors. The expected life of the option is based on observed historical patterns. The expected dividend yield is based on the projected annual dividend payment per share divided by the stock price at the date of grant. This amount was zero because we did not expect to pay dividends at the grant dates for the stock options awarded.

The following table summarizes activity for our stock options for the year ended December 31, 2012 (share data in thousands):

	Number of Shares			Weighted- Average Exercise Price		Weighted- Average Remaining Contractual Term		Aggregate Intrinsic Value (in  millions)
Outstanding at beginning of period		1,154		$	22.68
Granted		711			25.96
Exercised		(262	)		11.24
Cancelled/expired/forfeited		(171	)		29.05
Outstanding at end of period		1,432		$	25.65		5.2 Years	$	4.2
Exercisable at end of period		536		$	22.31		4.1 Years	$	3.5

The aggregate intrinsic value included in the table above represents the total pretax intrinsic value that would have been received by the option holders had all option holders exercised their options on December 31, 2012. The intrinsic value is calculated as the total number of option shares multiplied by the difference between the closing price of our common stock on the last trading day of the period and the exercise price of the options. This amount changes based on the price of our common stock.

The weighted-average fair value of the stock options granted in the years ended December 31, 2012, 2011 and 2010 was $7.30, $12.33 and $10.64, respectively.

During the years ended December 31, 2012, 2011 and 2010, the total intrinsic value of stock options exercised was $3.8 million, $7.5 million and $1.5 million, respectively. The actual tax benefits realized related to the stock options exercised during the year ended December 31, 2012 were $0.6 million.

B&W Restricted Stock

Nonvested restricted stock awards as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (share data in thousands):

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		13		$	20.58
Granted		—			—
Vested		(7	)		19.04
Cancelled/forfeited		—			—
Nonvested at end of period		6		$	22.39

B&W Performance Shares

Nonvested performance shares as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (share data in thousands):

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		477		$	33.56
Granted		493			26.09
Vested		—			—
Cancelled/forfeited		(171	)		30.77
Nonvested at end of period		799		$	29.55

The actual number of shares in which each participant vests is dependent upon achievement of certain Return on Invested Capital and Diluted Earnings Per Share targets over three-year performance periods. The number of shares in which participants can vest ranges from zero to 200% of the initial performance shares granted, to be determined upon completion of the three-year performance period. The number of shares included in the table above assumes the nonvested awards at the beginning of the period will vest at 180% of the target shares and awards granted during 2012 will vest at 100% of the target shares.

B&W Restricted Stock Units

Nonvested restricted stock units as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (share data in thousands):

	Number of Shares			Weighted- Average Grant Date Fair Value
Nonvested at beginning of period		491		$	22.25
Granted		365			25.53
Vested		(357	)		19.31
Cancelled/forfeited		(78	)		27.69
Nonvested at end of period		421		$	26.58

The actual tax benefits realized related to the restricted stock units vested during the year ended December 31, 2012 were $1.0 million.

Cash-Settled Stock Appreciation Rights

The fair value of each stock appreciation right grant was calculated at the grant date using Black-Scholes and was remeasured at the end of the reporting period with the following weighted-average assumptions:

	Year Ended December 31, 2012
Risk-free interest rate		0.50	%
Expected volatility		0.32
Expected life of the option in years		3.55
Expected dividend yield		1.23	%

The risk-free interest rate is based on the implied yield on a U.S. Treasury zero-coupon issue with a remaining term equal to the expected life of the stock appreciation right. The expected volatility is based on implied volatility from publicly traded options on our common stock, historical volatility of the price of our common stock and other factors. The expected life of the stock appreciation right is based on observed historical patterns and the length of time each award has been outstanding as of each measurement date. The expected dividend yield is based on the projected annual dividend payment per share divided by the stock price at the date of measurement.

The following table summarizes activity for our stock appreciation rights for the year ended December 31, 2012 (unit data in thousands):

	Number of Units			Weighted- Average Exercise Price		Weighted- Average Remaining Contractual Term		Aggregate Intrinsic Value (in  millions)
Outstanding at beginning of period		—		$	—
Granted		49			25.23
Exercised		—			—
Cancelled/expired/forfeited		(12	)		25.11
Outstanding at end of period		37		$	25.27		6.5 Years	$	0.0
Exercisable at end of period		—		$	—		—	$	—

The aggregate intrinsic value included in the table above represents the total pretax intrinsic value that would have been received by the stock appreciation rights holders had all holders exercised their rights on December 31, 2012. The intrinsic value is calculated as the total number of stock appreciation rights multiplied by the difference between the closing price of our common stock on the last trading day of the period and the exercise price of the stock appreciation rights. This amount changes based on the price of our common stock.

The weighted-average fair value as of December 31, 2012 for stock appreciation rights granted for the year ended December 31, 2012 was $5.96. This fair value is re-determined at the end of each reporting period for purposes of remeasuring compensation expense associated with these cash-settled awards.

Cash-Settled Performance Units

Nonvested cash-settled performance units as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (unit data in thousands):

	Number of Units			Weighted- Average Fair  Value
Nonvested at beginning of period		—
Granted		40
Vested		—
Cancelled/forfeited		(10	)
Nonvested at end of period		30		$	26.20

The actual number of units in which each participant vests is dependent upon achievement of certain Return on Invested Capital and Diluted Earnings Per Share targets over three-year performance periods. The number of units in which participants can vest ranges from zero to 200% of the initial performance units granted, to be determined upon completion of the three-year performance period. The number of units included as granted in the table above assumes the award will vest at 100% of the target units.

The weighted-average fair value for these cash-settled awards is based on our closing stock price as of December 31, 2012. The fair value is re-determined at the end of each reporting period for purposes of remeasuring compensation expense associated with these cash-settled awards.

Cash-Settled Restricted Stock Units

Nonvested restricted stock units as of December 31, 2012 and changes during the year ended December 31, 2012 were as follows (unit data in thousands):

	Number of Units			Weighted- Average Fair  Value
Nonvested at beginning of period		—
Granted		19
Vested		—
Cancelled/forfeited		(5	)
Nonvested at end of period		14		$	26.20

The weighted-average fair value for these cash-settled awards is based on our closing stock price as of December 31, 2012. The fair value is re-determined at the end of each reporting period for purposes of remeasuring compensation expense associated with these cash-settled awards.

MII Stock Options

The following summarizes the assumptions used for stock options granted to our employees prior to the spin-off. The fair value of each option grant was estimated at the date of grant using Black-Scholes, with the following weighted-average assumptions:

	Year Ended December 31, 2010
Risk-free interest rate		2.18	%
Expected volatility		0.55
Expected life of the option in years		4.79
Expected dividend yield		0	%

The risk-free interest rate was based on the implied yield on a U.S. Treasury zero-coupon issue with a remaining term equal to the expected life of the option. The expected volatility was based on implied volatility from publicly traded options on MII’s common stock, historical volatility of the price of MII’s common stock and other factors. The expected life of the option was based on observed historical patterns. The expected dividend yield is based on the projected annual dividend payment per share divided by the stock price at the date of grant. This amount is zero because MII did not pay cash dividends in recent years.

Thrift Plan

On August 13, 2010, 5,000,000 of the authorized and unissued shares of B&W common stock were reserved for issuance for the employer match to the Thrift Plan. Those matching employer contributions equal 50% of the first 6% of compensation, as defined in the Thrift Plan, contributed by participants, and fully vest and are nonforfeitable after three years of service or upon retirement, death, lay-off or approved disability. The Thrift Plan allows employees to sell their interest in B&W’s common stock fund at any time, except as limited by applicable securities laws and regulations. During the year ended December 31, 2012, we issued 549,121 shares of B&W’s common stock as employer contributions pursuant to the Thrift Plan. At December 31, 2012, 3,721,670 shares of B&W’s common stock remained available for issuance under the Thrift Plan.

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Derivative Financial Instruments (Narrative) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Derivative [Line Items]
Net gains deferred on derivative financial instruments in accumulated other comprehensive loss	$ 2,100,000
Notional amount of foreign currency forward contracts	170,300,000
Maturity date of foreign currency forward contracts	July 2014
Fair value of foreign currency forward contracts	3,300,000
Fair value of warrants	317,000	877,000	3,296,000
Stock Warrants [Member]
Derivative [Line Items]
Fair value of warrants	$ 300,000

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Stock-Based Compensation - Schedule of Changes in Nonvested Stock Awards (Detail) (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012
B&W Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested at beginning of period, Number of Shares	13
Granted, Number of Shares
Vested, Number of Shares	(7)
Cancelled/forfeited, Number of Shares
Nonvested at end of period, Number of Shares	6
Nonvested at beginning of period, Weighted-Average Grant Date Fair Value	$ 20.58
Granted, Weighted-Average Grant Date Fair Value
Vested, Weighted-Average Grant Date Fair Value	$ 19.04
Cancelled/forfeited, Weighted-Average Grant Date Fair Value
Nonvested at end of period, Weighted-Average Grant Date Fair Value	$ 22.39
B&W Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested at beginning of period, Number of Shares	491
Granted, Number of Shares	365
Vested, Number of Shares	(357)
Cancelled/forfeited, Number of Shares	(78)
Nonvested at end of period, Number of Shares	421
Nonvested at beginning of period, Weighted-Average Grant Date Fair Value	$ 22.25
Granted, Weighted-Average Grant Date Fair Value	$ 25.53
Vested, Weighted-Average Grant Date Fair Value	$ 19.31
Cancelled/forfeited, Weighted-Average Grant Date Fair Value	$ 27.69
Nonvested at end of period, Weighted-Average Grant Date Fair Value	$ 26.58
B&W Cash-Based Performance and Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested at beginning of period, Number of Shares	477
Granted, Number of Shares	493
Vested, Number of Shares
Cancelled/forfeited, Number of Shares	(171)
Nonvested at end of period, Number of Shares	799
Nonvested at beginning of period	$ 33.56
Granted, Aggregate Intrinsic Value	$ 26.09
Vested, Aggregate Intrinsic Value
Cancelled/forfeited, Aggregate Intrinsic Value	$ 30.77
Nonvested at end of period, Aggregate Intrinsic Value	$ 29.55

XML

Stock-Based Compensation - Schedule of Assumptions Used to Calculate Fair Value of Option Grant (Detail)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate	0.65%	1.52%	1.28%
Expected volatility	0.36%	0.46%	0.61%
Expected life of the option in years	3 years 11 months 23 days	3 years 9 months	4 years 29 days
Expected dividend yield	0.00%	0.00%	0.00%
McDermott International, Inc. [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate			2.18%
Expected volatility			0.55%
Expected life of the option in years			4 years 9 months 15 days
Expected dividend yield			0.00%
Cash Settled Stock Appreciation Rights [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Risk-free interest rate	0.50%
Expected volatility	0.32%
Expected life of the option in years	3 years 6 months 18 days
Expected dividend yield	1.23%

XML

Earnings Per Share (Computation of Basic and Diluted Earnings Per Share) (Detail) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Earnings Per Share [Line Items]
Net income attributable to The Babcock & Wilcox Company	$ 39,071	$ 51,443	$ 77,231	$ 59,950	$ (63,009)	$ 56,742	$ 58,665	$ 25,921	$ 227,695		$ 78,319		$ 139,939
Weighted average common shares, Basic									118,418,930		117,560,594		116,260,425
Net income attributable to The Babcock & Wilcox Company, Basic earnings per common share	$ 0.33	$ 0.43	$ 0.65	$ 0.51	$ (0.53)	$ 0.48	$ 0.50	$ 0.22	$ 1.92		$ 0.67		$ 1.20
Stock options, restricted stock and performance shares									602,394	[1]	844,003	[1]	1,365,640	[1]
Adjusted weighted average common shares									119,021,324		118,404,597		117,626,065
Net income attributable to The Babcock & Wilcox Company, Diluted earnings per common share	$ 0.33	$ 0.43	$ 0.65	$ 0.50	$ (0.53)	$ 0.48	$ 0.50	$ 0.22	$ 1.91		$ 0.66		$ 1.19
Antidilutive shares related to stock options excluded from the diluted share									1,082,904		742,035		349,744

[1] At December 31, 2012, 2011 and 2010, we excluded from the diluted share calculation 1,082,904, 742,035 and 349,744 shares, respectively, related to stock options, as their effect would have been antidilutive.

XML

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2012	Jan. 31, 2013	Jun. 29, 2012
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	FY
Trading Symbol	BWC
Entity Registrant Name	Babcock & Wilcox Co
Entity Central Index Key	0001486957
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		114,344,972
Entity Public Float			$ 2,900,000,000

XML

Commitments And Contingencies

12 Months Ended

Dec. 31, 2012

Commitments And Contingencies

NOTE 10 – COMMITMENTS AND CONTINGENCIES

Investigations and Litigation

Nuclear Fuel Services, Inc.

In June 2011, approximately 18 plaintiffs filed a lawsuit styled as a “class action” in the U.S. District Court for the Eastern District of Tennessee against NFS, B&W, Babcock & Wilcox Power Generation Group, Inc. (“B&W PGG”), Babcock & Wilcox Technical Services Group, Inc. (“B&W TSG”), NOG-Erwin Holdings, Inc. and others relating to the operation of the NFS facility in Erwin, Tennessee. In October 2011, the plaintiffs filed a motion to amend the original complaint increasing the number of plaintiffs to approximately 140, and we filed a motion to dismiss. In December 2012, the court issued an order denying the plaintiffs’ motion to amend the original complaint and granting our motion to dismiss, with prejudice, all claims. The plaintiffs did not appeal and the judgment became final in January 2013. The plaintiffs sought compensatory and punitive damages alleging personal injuries and property damage resulting primarily from alleged releases of radioactive and other hazardous materials as a result of operations at the facility.

Apollo and Parks Township

In January 2010, Michelle McMunn, Cara D. Steele and Yvonne Sue Robinson filed suit against B&W PGG, B&W TSG, formerly known as B&W Nuclear Environmental Services, Inc. (the “B&W Parties”) and Atlantic Richfield Company (“ARCO”) in the United States District Court for the Western District of Pennsylvania. Since January 2010, additional suits have been filed by additional plaintiffs and there are currently eleven lawsuits pending in the U.S. District Court for the Western District of Pennsylvania against the B&W Parties and ARCO. Following the dismissal of a number of claims in June 2012, and the February 4, 2013 filing of an additional 10 primary claims, the suits presently involve approximately 85 primary claimants alleging, among other things, personal injuries and property damage as a result of alleged releases of radioactive material relating to the operation, remediation, and/or decommissioning of two former nuclear fuel processing facilities located in Apollo Borough and Parks Township, Pennsylvania (collectively, the “Apollo and Parks Litigation”). Those facilities previously were owned by Nuclear Materials and Equipment Company, a former subsidiary of ARCO (“NUMEC”), which was acquired by B&W PGG. The plaintiffs in the Apollo and Parks Litigation seek compensatory and punitive damages. Eleven of the suits have been consolidated for most non-dispositive pre-trial matters. No action has been taken on the most recent filing. Discovery in the Apollo and Parks Litigation is ongoing and no trial date has been set.

At the time of ARCO’s sale of NUMEC stock to B&W PGG, B&W PGG received an indemnity and hold harmless agreement from ARCO with respect to claims and liabilities arising prior to or as a result of conduct or events predating the acquisition.

Insurance coverage and/or the ARCO indemnity currently provides coverage for the claims alleged in the Apollo and Parks Litigation, although no assurance can be given that insurance and/or the indemnity will be available or sufficient in the event of liability, if any.

The B&W Parties and ARCO were defendants in a prior litigation filed in 1994 relating to the operation of the Apollo and Parks Township facilities in the matter of Donald F. Hall and Mary Ann Hall, et al., v. Babcock & Wilcox Company, et al. (the “Hall Litigation”). In 1998, the B&W Parties settled all then-pending and future punitive damage claims in the Hall Litigation for $8.0 million and sought reimbursement from third parties, including its insurers, American Nuclear Insurers and Mutual Atomic Energy Liability Underwriters (“ANI”). In 2008, ARCO settled the Hall Litigation with the plaintiffs for $27.5 million. The B&W Parties then settled the Hall Litigation in 2009 for $52.5 million, settling approximately 250 personal injury and wrongful death claims, as well as approximately 125 property damage claims, alleging damages as a result of alleged releases involving the facilities. ARCO and the B&W Parties retained their insurance rights against ANI in their respective settlements; however, under a related settlement regarding ARCO’s indemnification of B&W PGG relating to the two facilities, ARCO assigned to the B&W Parties 58.33% of the total of all ARCO’s proceeds/amounts recovered against ANI on account of the Hall Litigation.

The B&W Parties sought recovery from ANI for amounts paid by the B&W Parties to settle the Hall Litigation, along with unreimbursed attorneys fees, allocated amounts assigned by ARCO to the B&W Parties, and applicable interest based upon ANI’s breach of contract and bad faith conduct in the matter of The Babcock & Wilcox Company et al. v. American Nuclear Insurers, et al. (the “ANI Litigation”). ARCO also sought recovery against ANI in the ANI Litigation, which has been pending before the Court of Common Pleas of Allegheny County, Pennsylvania.

In September 2011, a jury returned a verdict in the ANI Litigation, finding that the B&W Parties’ settlement of the Hall Litigation for $52.5 million and ARCO’s settlement for $27.5 million were fair and reasonable. Following the verdict, in February 2012, the B&W Parties, ARCO and ANI entered into an agreement in which the parties agreed to the dismissal with prejudice of all remaining claims pending in the ANI Litigation, excluding the B&W Parties’ and ARCO’s claims seeking reimbursement from ANI for the $52.5 million and $27.5 million settlements (plus interest) (the “Settlement Claims”). By agreement, ANI also waived: (1) any and all rights to appeal the September 2011 jury verdict on the basis of the trial court’s evidentiary rulings; and (2) any defenses and arguments of any kind except ANI’s position that it was not required to reimburse the B&W Parties and ARCO for their settlements under the provisions of the ANI policies. In February 2012, the Court granted the parties’ proposed order implementing their agreement and entered final judgment in favor of the B&W Parties and ARCO on the Settlement Claims. As part of the final order and judgment, the Court ruled that the B&W Parties and ARCO are entitled to pre-judgment interest on their $52.5 million and $27.5 million settlements, in the amounts of approximately $8.8 million and $6.2 million, respectively. In addition, post-verdict interest from the date of the jury verdict was awarded at 6%. In March 2012, ANI filed a notice of appeal as to the final judgment and a supersedeas appeal bond in the amount of 120% of the total final judgment amount. The parties have filed their respective briefs with the Superior Court and oral arguments were held October 31, 2012. No ruling has yet been issued by the court.

Execution on the final judgment is stayed pending ANI’s appeal in the Pennsylvania appellate courts. Pursuant to the agreement among the parties, if the final judgment is affirmed, following the exhaustion of all appeals, ANI must immediately satisfy the judgment and pay an additional liquidated contingency sum of $5 million to the B&W Parties and ARCO. If on appeal the final judgment is reversed and/or vacated, ANI will not owe the liquidated contingency sum. B&W has not recognized any amounts claimed in the ANI Litigation in its financial statements due to the uncertainty surrounding the ultimate amount to be realized.

Other Litigation and Settlements

Additionally, due to the nature of our business, we are, from time to time, involved in routine litigation or subject to disputes or claims related to our business activities, including, among other things:

• performance- or warranty-related matters under our customer and supplier contracts and other business arrangements; and

• workers’ compensation claims, premises liability claims and other claims.

Based upon our prior experience, we do not expect that any of these other litigation proceedings, disputes and claims will have a material adverse effect on our consolidated financial condition, results of operations or cash flows.

Environmental Matters

We have been identified as a potentially responsible party at various cleanup sites under the Comprehensive Environmental Response, Compensation, and Liability Act, as amended (“CERCLA”). CERCLA and other environmental laws can impose liability for the entire cost of cleanup on any of the potentially responsible parties, regardless of fault or the lawfulness of the original conduct. Generally, however, where there are multiple responsible parties, a final allocation of costs is made based on the amount and type of wastes disposed of by each party and the number of financially viable parties, although this may not be the case with respect to any particular site. We have not been determined to be a major contributor of wastes to any of these sites. On the basis of our relative contribution of waste to each site, we expect our share of the ultimate liability for the various sites will not have a material adverse effect on our consolidated financial condition, results of operations or cash flows in any given year.

The Department of Environmental Protection of the Commonwealth of Pennsylvania (“PADEP”) advised us in March 1994 that it would seek monetary sanctions and remedial and monitoring relief related to the Parks Facilities. The relief sought is related to potential groundwater contamination resulting from previous operations at the facilities. These facilities are currently owned by a subsidiary in our Nuclear Operations segment. PADEP has advised us that it does not intend to assess any monetary sanctions, provided our Nuclear Operations segment continues its remediation program for the Parks Facilities. Whether additional nonradiation contamination remediation will be required at the Parks Facilities remains unclear. Results from sampling completed by our Nuclear Operations segment have indicated that such remediation may not be necessary. Our Nuclear Operations segment continues to evaluate closure of the groundwater issues pursuant to applicable Pennsylvania law.

We perform significant amounts of work for the U.S. Government under both prime contracts and subcontracts and operate certain facilities that are licensed to possess and process special nuclear materials. As a result of these activities, we are subject to continuing reviews by governmental agencies, including the U.S. Environmental Protection Agency and the NRC.

The NRC’s decommissioning regulations require our Nuclear Operations and Technical Services segments to provide financial assurance that it will be able to pay the expected cost of decommissioning each of its licensed facilities at the end of its service life. We provided financial assurance aggregating $43.5 million during the year ended December 31, 2012 with existing letters of credit for the ultimate decommissioning of these licensed facilities. These two facilities have provisions in their government contracts pursuant to which substantially all of our decommissioning costs and financial assurance obligations are covered by the DOE, including the costs to complete the decommissioning projects underway at the facility in Erwin, Tennessee. These letters of credit are to cover decommissioning required pursuant to work not subject to this DOE obligation.

Our compliance with U.S. federal, state and local environmental control and protection regulations resulted in pretax charges of approximately $15.3 million in the year ended December 31, 2012. In addition, compliance with existing environmental regulations necessitated capital expenditures of $3.2 million in the year ended December 31, 2012. At December 31, 2012 and 2011, we had total environmental reserves (including provisions for the facilities discussed above) of $49.6 million and $47.3 million, respectively. Of our total environmental reserves at December 31, 2012 and 2011, $3.1 million and $3.2 million, respectively, were included in current liabilities. In the year ended December 31, 2010 we recognized an $8.7 million gain, included in cost of operations in our consolidated and combined statements of income, attributable to a change in estimate of an environmental liability at our NFS subsidiary. Inherent in the estimates of those reserves and recoveries are our expectations regarding the levels of contamination, decommissioning costs and recoverability from other parties, which may vary significantly as decommissioning activities progress. Accordingly, changes in estimates could result in material adjustments to our operating results, and the ultimate loss may differ materially from the amounts that we have provided for in our consolidated financial statements.

Operating Leases

Future minimum payments required under operating leases that have initial or remaining noncancellable lease terms in excess of one year at December 31, 2012 are as follows (in thousands):

Fiscal Year Ending December 31,	Amount
2013	$	10,314
2014	$	9,168
2015	$	10,751
2016	$	4,761
2017	$	4,207
Thereafter	$	4,734

Total rental expense for the years ended December 31, 2012, 2011 and 2010 was $12.1 million, $11.1 million and $10.5 million, respectively. These expense amounts include contingent rentals and are net of sublease income, neither of which is material.

XML

Pension Plans And Postretirement Benefits (Assumed Health-Care Cost Trend Rates) (Detail)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Health-care cost trend rate assumed for next year	8.50%	8.00%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)	4.50%	4.50%
Year that the rate reaches ultimate trend rate	2021	2019

XML

Stock-Based Compensation (Narrative) (Detail) (USD $) In Millions, except Share data, unless otherwise specified	12 Months Ended											3 Months Ended	12 Months Ended	5 Months Ended	12 Months Ended				1 Months Ended	12 Months Ended
	Dec. 31, 2012 Minimum [Member]	Dec. 31, 2012 Maximum [Member]	Dec. 31, 2012 Stock Options [Member]	Dec. 31, 2011 Stock Options [Member]	Dec. 31, 2010 Stock Options [Member]	Dec. 31, 2012 B&W Cash-Based Performance and Restricted Stock Units [Member]	Dec. 31, 2012 B&W Cash-Based Performance and Restricted Stock Units [Member] Minimum [Member]	Dec. 31, 2012 B&W Cash-Based Performance and Restricted Stock Units [Member] Maximum [Member]	Dec. 31, 2012 Restricted Stock Unit [Member]	Dec. 31, 2012 Stock Appreciation Right [Member]	Dec. 31, 2012 Cash Settled Performance Shares [Member]	Jun. 30, 2012 2012 Long-Term Incentive Plan [Member]	Dec. 31, 2012 2012 Long-Term Incentive Plan [Member]	Dec. 31, 2010 MII Legacy Stock-Based Compensation Plans [Member]	Dec. 31, 2012 MII Legacy Stock-Based Compensation Plans [Member]	Dec. 31, 2011 MII Legacy Stock-Based Compensation Plans [Member]	Dec. 31, 2010 MII Legacy Stock-Based Compensation Plans [Member]	Dec. 31, 2012 2012 Grants [Member] B&W Cash-Based Performance and Restricted Stock Units [Member]	Aug. 13, 2010 Thrift Plan [Member]	Dec. 31, 2012 Thrift Plan [Member]	Dec. 31, 2012 2010 Long-Tem Incentive Plan [Member]	Dec. 31, 2010 2010 Long-Tem Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized for issuance																			5,000,000			10,000,000
Minimum percentage of fair market value closing price												100.00%										100.00%
Expiry date of B&W common stock												7 years										7 years
Shares issued under the plan																				549,121	4,610,485
Shares available for issuance of awards in future																				3,721,670	5,389,515
Stock based compensation expense														$ 4.4	$ 18.3	$ 17.9	$ 16.3
Stock-based compensation, Tax benefits														2.6	6.9	6.6	6.0
Total unrecognized estimated compensation expense, nonvested awards													15.6
Estimated tax benefits of unrecognized compensation expense, nonvested awards													9.5
Total gross unrecognized estimated compensation expense													25.1
Unrecognized estimated compensation expense to be recognized, weighted-average period													1 year 10 months 24 days
Weighted-average fair value of options granted			$ 7.30	$ 12.33	$ 10.64					$ 5.96
Total intrinsic value of stock options exercised			3.8	7.5	1.5
Actual tax benefits realized related to the stock options exercised			0.6
Percentage of shares in which participants can vest	0.00%	100.00%					0.00%	200.00%
Rate of vesting assumed						180.00%												100.00%
Actual tax benefits realized related to restricted stock vested									$ 1.0
Vesting Period											3 years								3 years
Percentage of matching contribution by employer																			50.00%
Participants contributions as a percentage of compensation																			6.00%

XML

Condensed Consolidated Statements Of Income (USD $) In Thousands, except Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Revenues	$ 3,291,359	[1],[2]	$ 2,952,040	[1],[2]	$ 2,688,811	[1],[2]
Costs and Expenses:
Cost of operations	2,461,205		2,384,154		2,032,347
Research and development costs	120,562		106,396		69,167
Losses (gains) on asset disposals and impairments - net	1,419		(3,087)		38
Selling, general and administrative expenses	428,293		447,561		412,486
Total Costs and Expenses	3,011,479		2,935,024		2,514,038
Equity in Income of Investees	66,709		78,655		74,082
Operating Income	346,589	[3]	95,671	[3]	248,855	[3]
Other Income (Expense):
Interest income	1,491		1,342		1,187
Interest expense	(3,735)		(4,543)		(12,938)
Other income (expense) - net	(24,927)		2,028		(16,896)
Total Other Expense	(27,171)		(1,173)		(28,647)
Income before Provision for Income Taxes	319,418		94,498		220,208
Provision for Income Taxes	101,861		23,880		80,005
Net Income	217,557		70,618		140,203
Net Loss (Income) Attributable to Noncontrolling Interest	10,138		7,701		(264)
Net Income Attributable to The Babcock & Wilcox Company	$ 227,695		$ 78,319		$ 139,939
Basic:
Net income attributable to The Babcock & Wilcox Company	$ 1.92		$ 0.67		$ 1.20
Diluted:
Net Income Attributable to The Babcock & Wilcox Company	$ 1.91		$ 0.66		$ 1.19
Shares used in the computation of earnings per share (Note 19):
Basic	118,418,930		117,560,594		116,260,425
Diluted	119,021,324		118,404,597		117,626,065

[1] We allocate geographic revenues based on the location of the customer's operations.

[2] Segment revenues are net of the following intersegment transfers and other adjustments:

[3] (2) Included in operating income is the following:

XML

Income Taxes

12 Months Ended

Dec. 31, 2012

Income Taxes

NOTE 4 – INCOME TAXES

B&W and its subsidiaries are subject to U.S. federal income tax and income tax of multiple state and international jurisdictions. We provide for income taxes based on the tax laws and rates in the jurisdictions in which we conduct our operations. These jurisdictions may have regimes of taxation that vary with respect to nominal rates and with respect to the basis on which these rates are applied. This variation, along with the changes in our mix of income within these jurisdictions, can contribute to shifts in our effective tax rate from period to period.

The results of the U.S. operations of MII and/or certain of its subsidiaries were reflected in our consolidated return for U.S. federal income tax purposes and/or certain consolidated, combined and unitary returns for state, local and foreign tax purposes through June 7, 2010. The Statute of Limitations is closed for 2008 and prior tax years.

We are currently under audit by various state and international authorities. With few exceptions, we do not have any returns under examination for years prior to 2008.

We apply the provisions of FASB Topic Income Taxes regarding the treatment of uncertain tax positions. A reconciliation of unrecognized tax benefits follows:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
Balance at beginning of period	$	32,357		$	36,342		$	11,842
Increases based on tax positions taken in the current year		980			1,171			6,550
Increases based on tax positions taken in the prior years		65			3,269			343
Increases due to positions assumed at spin-off		—			—			24,181
Decreases based on tax positions taken in the prior years		(3,114	)		(4,329	)		(1,442	)
Decreases due to settlements with tax authorities		(1,101	)		(1,073	)		(5,132	)
Decreases due to lapse of applicable statute of limitation		(24,700	)		(3,023	)		—
Balance at end of period	$	4,487		$	32,357		$	36,342

The $4.5 million balance of unrecognized tax benefits at December 31, 2012 would reduce our effective tax rate if recognized.

In accordance with FASB Topic Income Taxes, we recognize interest and penalties related to unrecognized tax benefits in our provision for income taxes. During the year ended December 31, 2012, we recorded a reduction in our accruals of $0.8 million, resulting in recorded liabilities of approximately $0.3 million for the payment of tax-related interest and penalties. At December 31, 2011 and 2010, we recorded liabilities of approximately $1.1 million and $4.9 million, respectively, for the payment of tax-related interest and penalties.

We believe that, within the next 12 months, it is reasonably possible that our previously unrecognized tax benefits could decrease by approximately $1.0 million to $3.5 million.

Deferred income taxes reflect the net tax effects of temporary differences between the financial and tax bases of assets and liabilities. Significant components of deferred tax assets and liabilities as of December 31, 2012 and 2011 were as follows:

	December 31,
	2012			2011
	(In thousands)
Deferred tax assets:
Pension liability	$	201,229		$	216,248
Accrued warranty expense		26,695			33,412
Accrued vacation pay		13,312			13,269
Accrued liabilities for self-insurance (including postretirement health care benefits)		35,374			41,243
Accrued liabilities for executive and employee incentive compensation		39,483			29,539
Environmental and products liabilities		8,024			7,711
Investments in joint ventures and affiliated companies		16,993			3,704
Long-term contracts		29,807			22,871
Net operating loss carryforward		15,787			22,380
State tax net operating loss carryforward		21,757			22,734
Foreign tax credit carryforward		808			18,292
Other		7,722			8,273
Total deferred tax assets		416,991			439,676
Valuation allowance for deferred tax assets		(19,979	)		(9,354	)
Deferred tax assets		397,012			430,322
Deferred tax liabilities:
Property, plant and equipment		39,016			31,874
Investments in joint ventures and affiliated companies		1,064			791
Long-term contracts		30,571			27,681
Intangibles		24,756			26,365
Other		9,580			8,080
Total deferred tax liabilities		104,987			94,791
Net deferred tax assets	$	292,025		$	335,531

Income before provision for income taxes was as follows:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
U.S.	$	222,840	$	39,417	$	174,242
Other than U.S.		96,578		55,081		45,966
Income before provision for income taxes	$	319,418	$	94,498	$	220,208

The provision for income taxes consisted of:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Current:
U.S. – federal	$	39,784	$	24,591		$	29,191
U.S. – state and local		7,979		7,452			8,029
Other than U.S.		11,060		11,037			11,617
Total current		58,823		43,080			48,837
Deferred:
U.S. – Federal		24,560		(20,066	)		33,541
U.S. – State and local		6,545		5,195			(389	)
Other than U.S.		11,933		(4,329	)		(1,984	)
Total deferred (benefit) provision		43,038		(19,200	)		31,168
Provision for income taxes	$	101,861	$	23,880		$	80,005

The following is a reconciliation of the U.S. statutory federal tax rate (35%) to the consolidated and combined effective tax rate:

	Year Ended December 31,
	2012			2011			2010
U.S. federal statutory (benefit) rate		35.0	%		35.0	%		35.0	%
State and local income taxes		4.3			6.4			3.4
Foreign rate differential		(4.1	)		(11.8	)		(5.3	)
Foreign operations		0.5			6.4			0.4
Tax credits		(2.5	)		(46.8	)		(4.9	)
Dividends and deemed dividends from affiliates		2.3			38.7			9.1
Valuation allowances		3.4			7.6			(2.6	)
Uncertain tax positions		(9.0	)		(2.8	)		1.3
Non-deductible expenses		1.3			5.5			1.1
Additional spin related benefit		—			(4.6	)		—
Manufacturing deduction		(1.3	)		(3.6	)		(1.6	)
Minority interest		1.1			3.2			—
Other		0.9			(7.9	)		0.4
Effective tax rate		31.9	%		25.3	%		36.3	%

At December 31, 2012, we had a valuation allowance of $20.0 million for deferred tax assets, which we expect cannot be realized through carrybacks, future reversals of existing taxable temporary differences and our estimate of future taxable income. We believe that our remaining deferred tax assets are more likely than not realizable through carrybacks, future reversals of existing taxable temporary differences and our estimate of future taxable income. Any changes to our estimated valuation allowance could be material to our consolidated financial statements.

The following is an analysis of our valuation allowance for deferred tax assets:

	Beginning Balance			Charges To Costs and Expenses			Charged To Other Accounts		Effect Of Spin-Off(1)		Ending Balance
	(In thousands)
Year Ended December 31, 2012	$	(9,354	)		(10,625	)		—		—	$	(19,979	)
Year Ended December 31, 2011	$	(2,205	)		(7,149	)		—		—	$	(9,354	)
Year Ended December 31, 2010	$	(28,701	)		6,904			—		19,592	$	(2,205	)

⁽¹⁾  Effect of spin-off includes state tax valuation allowances distributed to MII in the spin-off.

We have foreign net operating loss carryforwards of $64.4 million available to offset future taxable income in foreign jurisdictions. Of the foreign net operating loss carryforwards, $3.1 million is scheduled to expire in 2015 to 2032. The foreign net operating losses have a valuation allowance of $0.9 million against the related deferred taxes. In addition, we have foreign tax credit carryovers of $0.8 million which will expire in 2013. We have state net operating losses of $408.5 million available to offset future taxable income in various states. Our state net operating loss carryforwards begin to expire in the year 2013. We are carrying a valuation allowance of $9.5 million against the deferred tax asset related to the state loss carryforwards.

We would be subject to withholding taxes if we were to distribute earnings from certain foreign subsidiaries. For the year ended December 31, 2012, the undistributed earnings of these subsidiaries were $271.1 million. Unrecognized deferred income tax liabilities, including withholding taxes, of approximately $20.0 million would be payable upon distribution of these earnings. We have provided tax of $2.0 million on earnings we intend to remit. All other earnings are considered permanently reinvested.

The American Taxpayer Relief Act of 2012 was signed into law on January 2, 2013. Some provisions of this law provide for retroactive changes to the 2012 tax year which we did not consider in determining our effective tax rate for 2012. The impact of these retroactive changes will be recorded in the first quarter of 2013.

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Equity Method Investments

12 Months Ended

Dec. 31, 2012

Equity Method Investments

NOTE 3 – EQUITY METHOD INVESTMENTS

We have investments in entities that we account for using the equity method. The undistributed earnings of our equity method investees were $115.5 million and $98.4 million at December 31, 2012 and 2011, respectively.

Summarized below is combined balance sheet and income statement information for investments accounted for under the equity method:

	December 31,
	2012		2011
	(In thousands)
Current assets	$	835,997	$	855,962
Noncurrent assets		271,233		211,920
Total Assets	$	1,107,230	$	1,067,882
Current liabilities	$	616,786	$	594,883
Noncurrent liabilities		89,285		112,936
Owners’ equity		401,159		360,063
Total Liabilities and Owners’ Equity	$	1,107,230	$	1,067,882

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
Revenues	$	2,758,159	$	2,669,923	$	2,283,256
Gross profit	$	210,425	$	271,920	$	258,598
Income before provision for income taxes	$	146,911	$	185,859	$	182,482
Provision for income taxes		9,000		14,258		21,230
Net Income	$	137,911	$	171,601	$	161,252

Revenues of equity method investees include $2,222.4 million, $1,956.7 million and $1,605.0 million of reimbursable costs recorded by limited liability companies in our Technical Services segment at December 31, 2012, 2011 and 2010, respectively. Our investment in equity method investees was $4.2 million more than our underlying equity in net assets of those investees based on stated ownership percentages at December 31, 2012. These differences were primarily related to the timing of distribution of dividends and various adjustments under GAAP.

The provision for income taxes is based on the tax laws and rates in the countries in which our investees operate. There is no expected relationship between the provision for income taxes and income before provision for income taxes. The taxation regimes vary not only by their nominal rates, but also by the allowability of deductions, credits and other benefits. For some of our U.S. investees, U.S. income taxes are the responsibility of the respective owners.

Reconciliation of net income per combined income statement information of our investees to equity in income of investees per our consolidated and combined statements of income is as follows:

	Year Ended December 31,
	2012		2011			2010
	(In thousands)
Equity income based on stated ownership percentages	$	66,064	$	81,971		$	77,882
All other adjustments due to amortization of basis differences, timing of GAAP adjustments and other adjustments		645		(3,316	)		(3,800	)
Equity in income of investees	$	66,709	$	78,655		$	74,082

Our transactions with unconsolidated affiliates were as follows:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
Sales to	$	42,538	$	49,400	$	45,321
Purchases from	$	1,814	$	980	$	4,693
Dividends received	$	51,594	$	57,801	$	53,633
Capital contributions, net of returns	$	6,289	$	38,176	$	5,412

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Derivative Financial Instruments

12 Months Ended

Dec. 31, 2012

Derivative Financial Instruments

NOTE 15 – DERIVATIVE FINANCIAL INSTRUMENTS

Our global operations give rise to exposure to market risks from changes in foreign currency exchange rates. We use derivative financial instruments, primarily foreign currency exchange (“FX”) forward contracts, to reduce the impact of changes in FX rates on our operating results. We use these instruments primarily to hedge our exposure associated with revenues or costs on our long-term contracts that are denominated in currencies other than our operating entities’ functional currencies. We do not hold or issue financial instruments for trading or other speculative purposes.

We enter into derivative financial instruments primarily as hedges of certain firm purchase and sale commitments denominated in foreign currencies. We record these contracts at fair value on our consolidated balance sheets. Depending on the hedge designation at the inception of the contract, the related gains and losses on these contracts are either deferred in stockholders’ equity as a component of accumulated other comprehensive income, until the hedged item is recognized in earnings, or offset against the change in fair value of the hedged firm commitment through earnings. Any ineffective portion of a derivative’s change in fair value and any portion excluded from the assessment of effectiveness are immediately recognized in other income (expense) – net in our consolidated and combined statements of income. The gain or loss on a derivative instrument not designated as a hedging instrument is also immediately recognized in earnings. Gains and losses on derivative financial instruments that require immediate recognition are included as a component of other income (expense) – net in our consolidated and combined statements of income.

We have designated all of our FX forward contracts that qualify for hedge accounting as cash flow hedges. The hedged risk is the risk of changes in functional-currency-equivalent cash flows attributable to changes in spot exchange rates of forecasted transactions related to long-term contracts. We exclude from our assessment of effectiveness the portion of the fair value of the forward contracts attributable to the difference between spot exchange rates and forward exchange rates. At December 31, 2012, we had deferred approximately $2.1 million of net gains on these derivative financial instruments in accumulated other comprehensive income. We expect to recognize this entire amount in the next twelve months.

At December 31, 2012, all of our derivative financial instruments consisted of FX forward contracts and warrants to purchase common stock. The notional amount of our FX forward contracts totaled $170.3 million at December 31, 2012, with maturities extending to July 2014. These instruments consist primarily of contracts to purchase or sell Canadian Dollars or Danish Kroner. The fair value of these contracts totaled $3.3 million, all of which are Level 2 in nature (See Note 16). The fair value of our warrants, which are related to our investment in USEC Inc. described in Note 2, totaled $0.3 million at December 31, 2012, and is Level 3 in nature. We are exposed to credit-related losses in the event of nonperformance by counterparties to derivative financial instruments. We attempt to mitigate this risk by using major financial institutions with high credit ratings. The counterparties to all of our FX forward contracts are financial institutions included in our credit facility. Our hedge counterparties have the benefit of the same collateral arrangements and covenants as described under this facility.

The following tables summarize our derivative financial instruments at December 31, 2012 and 2011:

	Asset and Liability Derivatives
	December 31,
	2012		2011
	(In thousands)
Derivatives Designated as Hedges:
Foreign Exchange Contracts:
Location
Accounts receivable-other	$	2,251	$	1,760
Other assets	$	3,777	$	3,792
Accounts payable	$	1,893	$	1,238
Other liabilities	$	29	$	610
Derivatives Not Designated as Hedges:
Foreign Exchange Contracts:
Location
Other assets	$	191	$	—
Accounts payable	$	962	$	520
Other liabilities	$	—	$	664
Stock Warrants:
Location
Other assets	$	317	$	877

The effects of derivatives on our financial statements are outlined below:

	December 31,
	2012			2011
	(In thousands)
Derivatives Designated as Hedges:
Cash Flow Hedges:
Foreign Exchange Contracts:
Amount of gain (loss) recognized in other comprehensive income	$	2,031		$	(1,224	)
Income (loss) reclassified from accumulated other comprehensive loss into income: effective portion
Location
Revenues	$	(1,082	)	$	4,128
Cost of operations	$	3,833		$	(2,350	)
Other-net	$	(24	)	$	373
Gain (loss) recognized in income: portion excluded from effectiveness testing
Location
Other-net	$	(185	)	$	1,045
Derivatives Not Designated as Hedges:
Forward Contracts:
Gain (loss) recognized in income
Location
Other-net	$	(169	)	$	1,234
Stock Warrants:
Loss recognized
Location
Other-net	$	(560	)	$	(2,419	)

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Related Party Transactions

12 Months Ended

Dec. 31, 2012

Related Party Transactions

NOTE 11 – RELATED PARTY TRANSACTIONS

Prior to the spin-off, we were party to transactions with MII and its subsidiaries occurring in the normal course of operations.

Certain corporate and general and administrative expenses have been allocated to MII and its subsidiaries based on a level of effort calculation. We allocated expense of $20.0 million in the seven months ended July 31, 2010, which represented the period prior to our spin-off date.

We included in interest expense $8.7 million in the nine months ended September 30, 2010 attributable to an intercompany loan with a subsidiary of MII.

In connection with the accounting change described in Note 1, we adjusted our equity and related transactions prior to the spin-off. We recorded a cumulative reduction in parent equity as of January 1, 2010 of $554.8 million. Additionally, the related party transactions discussed below impacted our equity.

Dividend – In June 2010, we paid a dividend of $100.0 million to MII to maintain appropriate working capital needs. This amount was based on a determination by the MII Board of Directors after a review of the MII consolidated cash position and the respective foreseeable working capital and liquidity requirements for each of MII and B&W following the spin-off.

Net Transactions with Parent – In connection with the spin-off, capital in excess of par value increased by $523.6 million. This increase consisted primarily of the forgiveness of intercompany balances owed to MII of $178.0 million, the noncash settlement of a note payable to an MII affiliate totaling $277.8 million and the distribution by B&W of certain net assets totaling $20.7 million to MII, including $43.3 million in cash. In addition to these transactions, MII paid B&W $43.3 million in cash to settle a note receivable, and B&W paid MII $43.4 million in settlement of certain intercompany amounts. In addition, MII contributed net assets to B&W which included $12.5 million in cash.

See Note 3 for additional transactions with unconsolidated affiliates.

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Pension Plans And Postretirement Benefits (Summary Of Total Investments Measured At Fair Value) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Total Assets	$ 2,165,018	$ 1,951,408
Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	649,978	550,146
Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	120,223	298,083
Commingled And Mutual Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	791,195	546,776
U.S. Government Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	425,709	313,458
Partnerships With Security Holdings [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	112,881	134,295
Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	14,516	53,560
Cash And Accrued Items [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	50,516	55,090
Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	602,829	674,755
Level 1 [Member] | Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	1,031
Level 1 [Member] | Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	120,220	298,077
Level 1 [Member] | Commingled And Mutual Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	9,084	8,250
Level 1 [Member] | U.S. Government Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	425,709	313,458
Level 1 [Member] | Cash And Accrued Items [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	46,785	54,970
Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	1,434,789	1,088,792
Level 2 [Member] | Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	648,947	550,146
Level 2 [Member] | Commingled And Mutual Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	782,111	538,526
Level 2 [Member] | Cash And Accrued Items [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	3,731	120
Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	127,400	187,861	207,244
Level 3 [Member] | Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	3	6
Level 3 [Member] | Partnerships With Security Holdings [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	112,881	134,295
Level 3 [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Total Assets	$ 14,516	$ 53,560

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Asset Sales And Impairment Of Long-Lived Assets

12 Months Ended

Dec. 31, 2012

Asset Sales And Impairment Of Long-Lived Assets

NOTE 7—ASSET SALES AND IMPAIRMENT OF LONG-LIVED ASSETS

We had net gains on asset sales of approximately $3.1 million during the year ended December 31, 2011, primarily attributable to the sale of a wholly owned manufacturing facility in a Chinese subsidiary of Babcock & Wilcox Power Generation Group, Inc. (“B&W PGG”).

During the years ended December 31, 2012, 2011 and 2010, we did not record any impairments of property, plant and equipment.

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Equity Method Investments (Narrative) (Detail) (USD $) In Millions, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule of Variable Interest Entities for Loans to Commercial Borrowers [Line Items]
Undistributed earnings of equity method investees	$ 115.5	$ 98.4
Reimbursable costs included in revenues of equity method investees	2,222.4	1,956.7	1,605.0
Investment in equity method investees in excess of underlying equity in net assets	4.2
Gain on sale of interest in joint venture	$ 1.2

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Segment Reporting (Schedule of Operating Income by Segment) (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended																12 Months Ended
	Dec. 31, 2012		Sep. 30, 2012		Jun. 30, 2012		Mar. 31, 2012		Dec. 31, 2011		Sep. 30, 2011		Jun. 30, 2011		Mar. 31, 2011		Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2010
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating income	$ 65,693	[1]	$ 84,399	[1]	$ 110,077	[1]	$ 86,420	[1]	$ (103,444)	[1]	$ 74,912	[1]	$ 82,809	[1]	$ 41,394	[1]	$ 346,589	[2]	$ 95,671	[2]	$ 248,855	[2]
Interest income																	1,491		1,342		1,187
(Gains) Losses on Asset Disposals - net																	(1,419)		3,087		(38)
Interest expense																	(3,735)		(4,543)		(12,938)
Equity in Income of Investees	18,119		14,546		16,687		17,357		22,131		22,782		18,381		15,361		66,709		78,655		74,082
Other income (expense)-net																	(24,927)		2,028		(16,896)
Total Other Expense																	(27,171)		(1,173)		(28,647)
Income before provision for income taxes																	319,418		94,498		220,208
Power Generation [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating income																	183,387		183,984		169,113
(Gains) Losses on Asset Disposals - net																	3,276		(3,456)		39
Equity in Income of Investees																	17,402		25,778		30,788
Nuclear Operations [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating income																	226,269		194,438		168,636
(Gains) Losses on Asset Disposals - net																	(339)
Equity in Income of Investees
Technical Services [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating income																	59,655		69,915		47,122
(Gains) Losses on Asset Disposals - net																	(1,517)				61
Equity in Income of Investees																	49,621		52,877		43,294
Nuclear Energy [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating income																	(62,879)		(116,887)		(26,442)
(Gains) Losses on Asset Disposals - net																	(1)		96		(62)
Equity in Income of Investees																	(314)
Segments [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating income																	406,432		331,450		358,429
Unallocated Corporate [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating income																	(27,953)	[3]	(20,361)	[3]	(18,029)	[3]
(Gains) Losses on Asset Disposals - net																			273
Mark to Market Adjustment [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Operating income																	$ (31,890)		$ (215,418)		$ (91,545)

[1] Includes equity in income of investees.

[2] (2) Included in operating income is the following:

[3] (1) Unallocated corporate includes general corporate overhead not allocated to segments

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Long-Term Debt And Notes Payable

12 Months Ended

Dec. 31, 2012

Long-Term Debt And Notes Payable

NOTE 5 – LONG-TERM DEBT AND NOTES PAYABLE

	December 31,
	2012			2011
	(In thousands)
Long-term debt consists of:
Secured Debt:
Power Generation – various notes payable	$	639		$	831
Other		5			7
		644			838
Less: Amounts due within one year		214			205
Long-term debt	$	430		$	633
Notes payable and current maturities of long-term debt consist of:
Short-term lines of credit	$	3,848		$	4,448
Current maturities of long-term debt		214			205
Total	$	4,062		$	4,653
Interest rate on short-term borrowing		6.6	%		7.2	%

Our short-term lines of credit represent borrowings by one of our subsidiaries. We have included this amount in notes payable and current maturities of long-term debt on our consolidated balance sheets. This facility is renewable annually and the interest rate associated with this line of credit was 6.6% per annum at December 31, 2012.

Maturities of long-term debt during the five years subsequent to December 31, 2012 are as follows: 2013 – $0.2 million; 2014 – $0.2 million; 2015 – $0.2 million; 2016 – $0.0 million; and 2017 – $0.0 million.

Credit Facility

On June 8, 2012, B&W entered into an Amended and Restated Credit Agreement (the “Credit Agreement”) with a syndicate of lenders and letter of credit issuers, and Bank of America, N.A., as administrative agent, which amends and restates our previous Credit Agreement dated May 3, 2010. The Credit Agreement provides for revolving credit borrowings and issuances of letters of credit in an aggregate outstanding amount of up to $700 million, and is scheduled to mature June 8, 2017. The proceeds of the Credit Agreement are available for working capital needs and other general corporate purposes. The Credit Agreement includes procedures for additional financial institutions to become lenders, or for any existing lender to increase its commitment thereunder, subject to an aggregate maximum of $1.0 billion for all revolving loan and letter of credit commitments.

The Credit Agreement is guaranteed by substantially all of B&W’s wholly owned domestic subsidiaries. Obligations under the Credit Agreement are secured by first-priority liens on certain assets owned by B&W and the guarantors (other than subsidiaries comprising our Nuclear Operations and Technical Services segments). If the corporate family rating of B&W and its subsidiaries from Moody’s is Baa3 or better (with a stable outlook or better), the corporate rating of B&W and its subsidiaries from S&P is BBB- or better (with a stable outlook or better), and other conditions are met, the liens securing obligations under the Credit Agreement will be released, subject to reinstatement upon the terms set forth in the Credit Agreement.

The Credit Agreement requires only interest payments on a periodic basis until maturity. We may prepay all loans under the Credit Agreement at any time without premium or penalty (other than customary LIBOR breakage costs), subject to certain notice requirements.

The Credit Agreement contains financial covenants relating to leverage and interest coverage and includes covenants that restrict, among other things, the level of debt incurrence, liens, investments, acquisitions, asset dispositions, dividends, prepayments of subordinated debt and mergers. At December 31, 2012, we were in compliance with all of the covenants set forth in the Credit Agreement. A comparison of the key financial covenants and current compliance at December 31, 2012 is as follows:

	Required	Actual
Maximum leverage ratio	Less than 2.75 to 1.0		0.06 to 1.0
Minimum interest coverage ratio	Greater than 4.0 to1.0		78.13 to 1.0

Loans outstanding under the Credit Agreement bear interest at our option at either the Eurocurrency rate plus a margin ranging from 1.25% to 2.25% per year or the base rate (the highest of the Federal Funds rate plus 0.50%, the one month Eurocurrency rate plus 1.0%, or the administrative agent’s prime rate) plus a margin ranging from 0.25% to 1.25% per year. The applicable margin for revolving loans varies depending on the credit ratings of the Credit Agreement. Under the Credit Agreement, we are charged a commitment fee on the unused portions of the Credit Agreement and that fee varies between 0.225% and 0.350% per year depending on the credit ratings of the Credit Agreement. Additionally, we are charged a letter of credit fee of between 1.25% and 2.25% per year with respect to the amount of each financial letter of credit issued under the Credit Agreement and a letter of credit fee of between 0.80% and 1.25% per year with respect to the amount of each performance letter of credit issued under the Credit Agreement, in each case depending on the credit ratings of the Credit Agreement. We also pay customary fronting fees and other fees and expenses in connection with the issuance of letters of credit under the Credit Agreement. In connection with entering into the Credit Agreement, we paid upfront fees to the lenders thereunder, and arrangement and other fees to the arrangers and agents of the Credit Agreement. At December 31, 2012, there were no borrowings outstanding and letters of credit issued under the Credit Agreement totaled $157.9 million, resulting in $542.1 million available for borrowings or to meet letter of credit requirements. The applicable interest rate at December 31, 2012 under this facility was 3.75% per year for revolving loans.

Based on the current credit ratings of the Credit Agreement, the applicable margin for Eurocurrency loans is 1.50%, the applicable margin for base rate loans is 0.50%, the letter of credit fee for financial letters of credit is 1.50%, the letter of credit fee for performance letters of credit is 0.875%, and the commitment fee for unused portions of the Credit Agreement is 0.25%. The Credit Agreement does not have a floor for the base rate or the Eurocurrency rate.

The Credit Agreement generally includes customary events of default for a secured credit facility. If any default occurs under the Credit Agreement, or if we are unable to make any of the representations and warranties in the Credit Agreement, we will be unable to borrow funds or have letters of credit issued under the Credit Agreement.

Other Arrangements

Certain foreign subsidiaries in our Power Generation segment have credit arrangements with various commercial banks and other financial institutions for the issuance of bank guarantees in association with contracting activity. The aggregate value of all such bank guarantees as of December 31, 2012 was $59.4 million.

B&W and certain of its subsidiaries have jointly executed general agreements of indemnity in favor of surety underwriters relating to surety bonds those underwriters issue in support of some of our contracting activity. As of December 31, 2012, bonds issued and outstanding under these arrangements in support of contracts totaled approximately $468.6 million.

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Pension Plans And Postretirement Benefits

12 Months Ended

Dec. 31, 2012

Pension Plans And Postretirement Benefits

NOTE 6 – PENSION PLANS AND POSTRETIREMENT BENEFITS

We have historically provided defined benefit retirement benefits, primarily through noncontributory pension plans, for most of our regular employees. As of 2006, our retirement plans for U.S.-based employees were closed to new entrants for our corporate employees and were closed to new salaried plan entrants for our existing plans within our Power Generation and Nuclear Operations segments. Effective October 31, 2008, the salaried and hourly retirement plans acquired with Marine Mechanical Corporation were merged into the retirement plan for our Nuclear Operations segment. Effective December 31, 2008, we acquired the retirement plans and postretirement benefit plans of NFS.

We do not provide retirement benefits to certain non-resident alien employees of foreign subsidiaries. Retirement benefits for salaried employees who accrue benefits in a defined benefit plan are based on final average compensation and years of service, while benefits for hourly paid employees are based on a flat benefit rate and years of service. Our funding policy is to fund the plans as recommended by the respective plan actuaries and in accordance with the Employee Retirement Income Security Act of 1974, as amended, or other applicable law. The Pension Protection Act of 2006 became effective in 2008. Funding provisions under the Pension Protection Act accelerate funding requirements to ensure full funding of benefits accrued. Assuming we continue as a government contractor, our contractual arrangements with the U.S. Government provide for the recovery of contributions to our pension and other postretirement benefit plans covering employees working primarily in our Nuclear Operations segment.

In October 2012, we notified employees that, effective December 31, 2015, benefit accruals for those salaried employees covered by, and continuing to accrue service and salary adjusted benefits under our major U.S. and Canadian defined benefit qualified pension plans will cease. This amendment is reflected as a curtailment at December 31, 2012. Furthermore, effective January 1, 2016, we will make service-based, cash contributions to The Babcock & Wilcox Company Thrift Plan (“Thrift Plan”) for those employees impacted by the plan freeze.

Effective January 1, 2012, a defined contribution component was adopted applicable to Babcock & Wilcox Canada, Ltd. (the “Canadian Plans”). Any employee with less than two years of continuous service as of December 31, 2011 was required to enroll in the defined contribution component of the Canadian Plans as of January 1, 2012 or upon the completion of six months of continuous service, whichever is later. These and future employees will not be eligible to enroll in the defined benefit component of the Canadian Plans. This amendment to the Canadian Plans is reflected as a curtailment at December 31, 2012.

Prior to the spin-off, the combined statements included the pension liability of the Retirement Plan for Employees of McDermott Incorporated and Participating Subsidiary and Affiliated Companies (the “MI Plan”). In connection with the spin-off, the majority of the MI Plan pension liability, along with the subsidiary holding this liability, was transferred to MII.

We make available other benefits which include postretirement health care and life insurance benefits to certain salaried and union retirees based on their union contracts. Certain subsidiaries provide these benefits to unionized and salaried future retirees.

As described in Note 1, we elected to change our accounting method for recognizing actuarial gains and losses for our pension and other postretirement benefit plans. Accordingly, we have made revisions to previously disclosed amounts, specifically net periodic benefit cost and accumulated other comprehensive income, where certain amounts have been reclassified to retained earnings.

Obligations and Funded Status

	Pension Benefits Year Ended December 31,						Other Benefits Year Ended December 31,
	2012			2011			2012			2011
	(In thousands)
Change in benefit obligation:
Benefit obligation at beginning of period	$	2,687,007		$	2,479,783		$	122,460		$	125,692
Service cost		46,828			43,495			1,138			1,143
Interest cost		122,605			134,927			5,124			5,805
Plan participants’ contributions		300			318			115			116
Curtailments		(94,642	)		—			—			—
Amendments		2,996			2,055			(1,302	)		(1,351	)
Settlements		(57,430	)		(13,625	)		—			—
Actuarial loss (gain)		198,935			181,517			(2,153	)		1,491
Foreign currency exchange rate changes		6,793			(5,633	)		220			(211	)
Benefits paid		(133,402	)		(135,830	)		(9,346	)		(10,225	)
Benefit obligation at end of period	$	2,779,990		$	2,687,007		$	116,256		$	122,460
Change in plan assets:
Fair value of plan assets at beginning of period	$	1,917,850		$	1,782,048		$	33,558		$	33,389
Actual return on plan assets		207,728			115,787			2,233			723
Plan participants’ contributions		300			318			115			116
Company contributions		187,284			174,639			10,764			9,555
Settlements		(57,430	)		(13,625	)		—			—
Foreign currency exchange rate changes		5,364			(5,487	)		—			—
Benefits paid		(133,402	)		(135,830	)		(9,346	)		(10,225	)
Fair value of plan assets at the end of period		2,127,694			1,917,850			37,324			33,558
Funded status	$	(652,296	)	$	(769,157	)	$	(78,932	)	$	(88,902	)
Amounts recognized in the balance sheet consist of:
Accrued employee benefits	$	(75,119	)	$	(185,832	)	$	(7,724	)	$	(8,239	)
Accumulated postretirement benefit obligation		—			—			(71,208	)		(80,663	)
Pension liability		(577,177	)		(583,337	)		—			—
Prepaid pension		—			12			—			—
Accrued benefit liability, net	$	(652,296	)	$	(769,157	)	$	(78,932	)	$	(88,902	)
Amount recognized in accumulated comprehensive income (before taxes):
Prior service cost (credit)	$	18,327		$	19,949		$	(2,523	)	$	(1,360	)
Supplemental information:
Plans with accumulated benefit obligation in excess of plan assets
Projected benefit obligation	$	2,779,990		$	2,686,796			N/A			N/A
Accumulated benefit obligation	$	2,723.930		$	2,515,868		$	116,256		$	122,460
Fair value of plan assets	$	2,127,694		$	1,917,626		$	37,324		$	33,558
Plans with plan assets in excess of accumulated benefit obligation
Projected benefit obligation	$	—		$	211			N/A			N/A
Accumulated benefit obligation	$	—		$	211		$	—		$	—
Fair value of plan assets	$	—		$	224		$	—		$	—

	Pension Benefits Year Ended December 31,									Other Benefits Year Ended December 31,
	2012			2011			2010			2012			2011			2010
	(In thousands)
Components of net periodic benefit cost:
Service cost	$	46,828		$	43,495		$	39,176		$	1,138		$	1,143		$	1,069
Interest cost		122,605			134,927			142,092			5,124			5,805			7,284
Expected return on plan assets		(136,913	)		(148,347	)		(136,364	)		(1,930	)		(1,919	)		(1,744	)
Amortization of prior service cost		3,579			3,721			3,711			(139	)		33			28
Recognized net actuarial loss (gain)		34,496			212,802			106,805			(2,456	)		2,952			(14,997	)
Net periodic benefit cost (income)	$	70,595		$	246,598		$	155,420		$	1,737		$	8,014		$	(8,360	)

Recognized net actuarial loss (gain) consists primarily of our reported actuarial loss (gain), curtailments, and the difference between the actual return on plan assets and the expected return on plan assets. These amounts are disclosed in this Note 6. As discussed in Note 17, we have excluded the recognized net actuarial loss (gain) from our reportable segments and such amount has been reflected in Note 17 as the Mark to Market Adjustment in the reconciliation of reportable segment income to consolidated operating income.

Additional Information

	Pension Benefits Year Ended December 31,						Other Benefits Year Ended December 31,
	2012			2011			2012		2011
	(In thousands)
Increase (decrease) in accumulated other comprehensive income due to actuarial losses—before taxes	$	(1,957	)	$	(3,258	)	$	1,302	$	1,616

In the current fiscal year, we have recognized expense (income) in other comprehensive income as components of net periodic benefit cost approximately $3.6 million and $(0.1) million for our pension benefits and other benefits, respectively. In the next fiscal year, we expect to recognize expense (income) in other comprehensive income as components of net periodic benefit cost approximately $3.7 million and $(0.3) million for our pension benefits and other benefits, respectively.

Assumptions

	Pension Benefits						Other Benefits
	2012			2011			2012			2011
Weighted average assumptions used to determine net periodic benefit obligations at December 31:
Discount rate		4.09	%		4.76	%		3.43	%		4.35	%
Rate of compensation increase		2.57	%		3.69	%		—			—
Weighted average assumptions used to determine net periodic benefit cost for the years ended December 31:
Discount rate		4.76	%		5.56	%		4.34	%		4.92	%
Expected return on plan assets		7.08	%		8.24	%		5.76	%		5.76	%
Rate of compensation increase		3.69	%		3.69	%		—			—

The expected rate of return on plan assets assumption is based on the long-term expected returns for the investment mix of assets currently in the portfolio. In setting this rate, we use a building-block approach. Historic real return trends for the various asset classes in the plan’s portfolio are combined with anticipated future market conditions to estimate the real rate of return for each class. These rates are then adjusted for anticipated future inflation to determine estimated nominal rates of return for each class. The expected rate of return on plan assets is determined to be the weighted average of the nominal returns based on the weightings of the classes within the total asset portfolio. We are using an expected return on plan assets assumption of 7.2% for the majority of our existing pension plan assets (approximately 89% of our total pension assets at December 31, 2012).

Our existing other benefit plans are unfunded, with the exception of the NFS postretirement benefit plans. These plans provide health benefits to certain salaried and hourly employees, as well as retired employees, of NFS. Approximately 85% of total assets for these postretirement benefit plans are contributed into a Voluntary Employees’ Beneficiary Association trust.

	2012			2011
Assumed health-care cost trend rates at December 31
Health-care cost trend rate assumed for next year		8.50	%		8.00	%
Rates to which the cost trend rate is assumed to decline (ultimate trend rate)		4.50	%		4.50	%
Year that the rate reaches ultimate trend rate		2021			2019

Assumed health-care cost trend rates have a significant effect on the amounts we report for our health-care plan. A one-percentage-point change in our assumed health-care cost trend rates would have the following effects:

	One-Percentage- Point Increase		One-Percentage- Point Decrease
	(In thousands)
Effect on total of service and interest cost	$	475	$	(401	)
Effect on postretirement benefit obligation	$	7,756	$	(6,456	)

Investment Goals

General

The overall investment strategy of the pension trusts is to achieve long-term growth of principal, while avoiding excessive risk and to minimize the probability of loss of principal over the long term. The specific investment goals that have been set for the pension trusts in the aggregate are (1) to ensure that plan liabilities are met when due and (2) to achieve an investment return on trust assets consistent with a reasonable level of risk.

Allocations to each asset class for both domestic and foreign plans are reviewed periodically and rebalanced, if appropriate, to assure the continued relevance of the goals, objectives and strategies. The pension trusts for both our domestic and foreign plans employ a professional investment advisor and a number of professional investment managers whose individual benchmarks are, in the aggregate, consistent with the plan’s overall investment objectives. The goals of each investment manager are (1) to meet (in the case of passive accounts) or exceed (for actively managed accounts) the benchmark selected and agreed upon by the manager and the Trust and (2) to display an overall level of risk in its portfolio that is consistent with the risk associated with the agreed upon benchmark.

The investment performance of total portfolios, as well as asset class components, is periodically measured against commonly accepted benchmarks, including the individual investment manager benchmarks. In evaluating investment manager performance, consideration is also given to personnel, strategy, research capabilities, organizational and business matters, adherence to discipline and other qualitative factors that may impact the ability to achieve desired investment results.

Domestic Plans

We sponsor the following domestic defined benefit plans:

• Retirement Plan for Employees of Babcock & Wilcox Commercial Operations (covering Power Generation and Nuclear Energy segment employees);

• Retirement Plan for Employees of Babcock & Wilcox Governmental Operations (covering Nuclear Operations and Technical Services segment employees and Corporate employees);

• Nuclear Fuel Services, Inc. Retirement Plan for Salaried Employees; and

• Nuclear Fuel Services, Inc. Retirement Plan for Hourly Employees.

The assets of the domestic pension plans are commingled for investment purposes and held by the Trustee, The Bank of New York Mellon, in The Babcock & Wilcox Company Master Trust (the “Master Trust”). For the years ended December 31, 2012 and 2011, the investment return on domestic plan assets of the Master Trust (net of deductions for management fees) was approximately 12% and 7%, respectively.

The following is a summary of the asset allocations for the Master Trust at December 31, 2012 and 2011 by asset category:

	2012			2011
Asset Category:
Commingled and Mutual Funds		34	%		25	%
Fixed Income (excluding U. S. Government Securities)		29	%		27	%
U.S. Government Securities		22	%		18	%
Equity Securities		6	%		17	%
Partnerships with Security Holdings		6	%		8	%
Real Estate		1	%		3	%
Other		2	%		2	%
Total		100	%		100	%

The target allocation for 2013 for the domestic plans, by asset class, is as follows:

Asset Class:
Fixed Income	55	%
Equities	45	%

Foreign Plans

We sponsor various plans through certain of our foreign subsidiaries. These plans are the Canadian Plans and the Diamond Power Specialty Limited Retirement Benefits Plan (the “Diamond UK Plan”).

The combined weighted average asset allocations of these plans at December 31, 2012 and 2011 by asset category were as follows:

	2012			2011
Asset Category:
Equity Securities and Commingled Mutual Funds		58	%		56	%
Fixed Income		40	%		41	%
Other		2	%		3	%
Total		100	%		100	%

The target allocation for 2013 for the foreign plans, by asset class, is as follows:

	Canadian Plans			Diamond UK Plan
Asset Class:
U. S. Equity		17	%		9	%
Global Equity		38	%		46	%
Fixed Income		45	%		45	%

Fair Value

See Note 16 for a detailed description of fair value measurements and the hierarchy established for valuation inputs. The following is a summary of total investments for our plans measured at fair value at December 31, 2012:

	12/31/12		Level 1		Level 2		Level 3
	(In thousands)
Pension and Other Benefits:
Fixed Income	$	649,978	$	1,031	$	648,947	$	—
Equities		120,223		120,220		—		3
Commingled and Mutual Funds		791,195		9,084		782,111		—
U.S. Government Securities		425,709		425,709		—		—
Partnerships with Security Holdings		112,881		—		—		112,881
Real Estate		14,516		—		—		14,516
Cash and Accrued Items		50,516		46,785		3,731		—
Total Assets	$	2,165,018	$	602,829	$	1,434,789	$	127,400

The following is a summary of total investments for our plans measured at fair value at December 31, 2011:

	12/31/11		Level 1		Level 2		Level 3
	(In thousands)
Pension and Other Benefits:
Fixed Income	$	550,146	$	—	$	550,146	$	—
Equities		298,083		298,077		—		6
Commingled and Mutual Funds		546,776		8,250		538,526		—
U.S. Government Securities		313,458		313,458		—		—
Partnerships with Security Holdings		134,295		—		—		134,295
Real Estate		53,560		—		—		53,560
Cash and Accrued Items		55,090		54,970		120		—
Total Assets	$	1,951,408	$	674,755	$	1,088,792	$	187,861

The following is a summary of the changes in the Plans’ Level 3 instruments measured on a recurring basis for the years ended December 31, 2012 and 2011:

	Year ended December 31,
	2012			2011
	(In thousands)
Balance at beginning of period	$	187,861		$	207,244
Issuances and acquisitions		12,593			16,821
Dispositions		(74,329	)		(52,572	)
Realized gain		692			5,897
Unrealized gain		583			10,471
Balance at end of period	$	127,400		$	187,861

Our Level 3 instruments include assets with no market price but rather calculations of net asset values per share or its equivalent. When appropriate, we adjust these net asset values for contributions and distributions, if any, made during the period beginning on the latest net asset value valuation date and ending on our measurement date. We also consider available market data, relevant index returns, preliminary estimates from our investees and other data obtained through research and consultation with third party advisors in determining the fair value of our Level 3 instruments.

Cash Flows

	Domestic Plans				Foreign Plans
	Pension Benefits		Other Benefits		Pension Benefits		Other Benefits
	(In thousands)
Expected employer contributions to trusts of defined benefit plans:
2013	$	52,000	$	2,082	$	20,040		N/A
Expected benefit payments:
2013		127,558		12,500		11,389		596
2014		133,785		11,768		12,075		621
2015		139,444		10,581		12,731		613
2016		144,617		9,470		13,671		598
2017		149,047		8,163		14,116		618
2018-2022		785,955		28,708		79,572		3,315

The expected employer contributions to trusts for 2013 are included in current liabilities at December 31, 2012.

Defined Contribution Plans

We provide benefits under The Babcock & Wilcox Company Supplemental Executive Retirement Plan (“SERP Plan”), which is a defined contribution plan. Prior to the spin-off, we participated in the McDermott International, Inc. SERP Plan. We recorded expense related to the SERP Plan of approximately $0.6 million, $0.3 million and $0.7 million in the years ended December 31, 2012, 2011 and 2010, respectively.

We also provide benefits under the Thrift Plan. The Thrift Plan generally provides for matching employer contributions of 50% of participants’ contributions up to 6 percent of compensation. These matching employer contributions are typically made in shares of BWC common stock. Prior to the spin-off, we participated in the Thrift Plan for Employees of McDermott Incorporated and Participating Subsidiary and Affiliated Companies (“MI Thrift Plan”). The MI Thrift Plan also provided for matching employer contributions of 50% of participants’ contributions up to 6 percent of compensation and employer contributions were typically made in shares of MII common stock. We also provide service-based cash contributions under the Thrift Plan to employees not accruing benefits under our defined benefit plans. Amounts charged to expense for employer contributions under the Thrift Plan and MI Thrift Plan totaled approximately $24.2 million, $22.1 million and $19.7 million in the years ended December 31, 2012, 2011 and 2010, respectively.

Effective January 1, 2012, we adopted The Babcock & Wilcox Company Defined Contribution Restoration Plan (the “Restoration Plan”) to restore benefits that would be provided to participants in the Thrift Plan but are precluded by the application of certain sections of the Internal Revenue Code of 1986, as amended (the “Code”). Each participant who is precluded from receiving the full amount of service-based contributions otherwise provided under the Thrift Plan in a plan year by the application of Code Section 401(a)(17) or 415(c) shall be credited with a employer service-based contribution for such plan year equal to the excess of the amount of service-based contributions that would have been made to the participant’s Thrift Plan account without the application of Code Section 401(a)(17) and 415(c) for the plan year over the amount of service-based contribution actually made to such Participant’s Thrift Plan account for the plan year. In addition, the Restoration Plan permits participants who are precluded from making the full amount of employee contributions to the Thrift Plan and receiving associated employer matching contributions by the application of Code Sections 401(a)(17) and 415(c) to elect to make deferral contributions and receive associated employer matching contributions under the Restoration Plan. Amounts charged to expense under the Restoration Plan totaled approximately $0.1 million in the year ended December 31, 2012.

Effective January 1, 2012, a defined contribution component was added to those Canadian Plans previously offering defined benefits to salaried employees. As of January 1, 2012, we made cash, service-based contributions under this arrangement. The amount charged to expense for employer contributions was approximately $0.5 million in the year ended December 31, 2012.

Multiemployer Plans

One of our subsidiaries in the Power Generation segment contributes to various multiemployer plans. The plans generally provide defined benefits to substantially all unionized workers in this subsidiary. Effective December 31, 2011, we adopted the disclosure provisions pertaining to these benefits that were issued in September, 2011 under FASB subtopic Compensation—Retirement Benefits—Multiemployer Plans.

The following table summarizes our contributions to multiemployer plans for the years covered by this report:

		Pension Protection										Expiration Date
		Act Zone		FIP/RP Status	Contributions							Of Collective
		Zone Status		Pending/	2012		2011		2010		Surcharge	Bargaining
Pension Fund	EIN/PIN	2012	2011	Implemented	(in millions)						Imposed	Agreement
Boilermaker-Blacksmith National Pension Trust	48-6168020/ 001	Yellow	Yellow	Yes	$	18.9	$	25.9	$	12.4	No	Described Below
All Other						5.3		5.5		6.0
					$	24.2	$	31.4	$	18.4

The Boilermaker-Blacksmith National Pension Trust (the “Boilermaker Plan”) is, by plan, the only significant contribution of our total contributions to these funds. Our collective bargaining agreements with the Boilermaker Plan are under a National Maintenance Agreement platform which is evergreen in terms of expiration. However, the agreement allows for termination by either party with a 90-day written notice. Our contributions to the Boilermaker Plan constitute less than 5% of total contributions to the plan. All other contributions expense for all periods included in this report represents multiple amounts to various plans that, individually, are deemed to be insignificant.

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Capital Stock

12 Months Ended

Dec. 31, 2012

Capital Stock

NOTE 8—CAPITAL STOCK

B&W was a wholly owned subsidiary of MII, until July 30, 2010 when MII distributed 100% of our outstanding common stock to the MII shareholders. On July 2, 2010, MII’s Board of Directors approved the spin-off of B&W through the distribution of shares of B&W common stock to holders of MII common stock. The distribution of B&W common stock was made on July 30, 2010, and consisted of one share of B&W common stock for every two shares of MII common stock to holders of MII common stock. On July 30, 2010, 116,225,732 shares of our common stock were distributed to MII shareholders to complete our spin-off from MII.

On November 5, 2012, our board of directors declared a dividend of $0.08 per share payable on December 17, 2012 to shareholders of record on November 19, 2012. In addition, our board authorized us to repurchase an indeterminate number of shares of our common stock at an aggregate value of up to $250 million. We may repurchase shares from time to time during a two-year period in the open market. As of December 31, 2012, we have repurchased 3,908,684 shares of common stock for approximately $96.7 million. On February 8, 2013, our board of directors declared a dividend of $0.08 per share payable on March 12, 2013 to shareholders of record on February 19, 2013.

We issue shares of our common stock in connection with our 2010 Long-Term Incentive Plan, and contributions to our Thrift Plan. At December 31, 2012, 9,111,185 shares of common stock were reserved for issuance in connection with those plans.

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Equity Method Investments (Schedule Of Transactions With Unconsolidated Affiliates) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule of Variable Interest Entities for Loans to Commercial Borrowers [Line Items]
Sales to	$ 42,538	$ 49,400	$ 45,321
Purchases from	1,814	980	4,693
Dividends received	51,594	57,801	53,633
Capital contributions, net of returns	$ 6,289	$ 38,176	$ 5,412

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Effect Of Accounting Change (Narrative) (Detail) (USD $) In Millions, unless otherwise specified	1 Months Ended
	Jan. 31, 2010
Change in Accounting Estimate [Line Items]
Cumulative reduction to parent equity	$ 554.8

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Pension Plans And Postretirement Benefits (Summary Of Changes In Plans' Level 3 Instruments Measured On Recurring Basis) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of period	$ 1,951,408
Realized gain
Unrealized gain (loss)
Fair value of plan assets at the end of period	2,165,018	1,951,408
Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of period	187,861	207,244
Issuances and acquisitions	12,593	16,821
Dispositions	(74,329)	(52,572)
Realized gain	692	5,897
Unrealized gain (loss)	583	10,471
Fair value of plan assets at the end of period	$ 127,400	$ 187,861

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Income Taxes (Narrative) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Income Tax Contingency [Line Items]
Unrecognized tax benefits that would reduce effective tax rate if recognized	$ 4,500,000
Reduction in accruals	800,000
Liability for the payment of tax related interest and penalties	300,000	1,100,000	4,900,000
Possible decrease in unrecognized tax benefits, maximum	3,500,000
Possible decrease in unrecognized tax benefits, minimum	1,000,000
Valuation Allowance for deferred tax asset	19,979,000	9,354,000	2,205,000	28,701,000
Net operating loss carryforwards	64,400,000
Foreign net operating loss carryforwards scheduled to expire	3,100,000
Undistributed earnings of subsidiaries	271,100,000
Unrecognized deferred income tax liabilities	20,000,000
Tax benefit on earnings with intent to remit	2,000,000
Foreign [Member]
Income Tax Contingency [Line Items]
Net operating loss carryforwards, valuation allowance	900,000
Foreign tax credit carryovers	800,000
Foreign [Member] | Minimum [Member]
Income Tax Contingency [Line Items]
Net operating loss carryforwards, expiration date	2015
Foreign [Member] | Maximum [Member]
Income Tax Contingency [Line Items]
Net operating loss carryforwards, expiration date	2032
State [Member]
Income Tax Contingency [Line Items]
Net operating loss carryforwards	408,500,000
Net operating loss carryforwards, valuation allowance	$ 9,500,000
State [Member] | Minimum [Member]
Income Tax Contingency [Line Items]
Net operating loss carryforwards, expiration date	2013

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Investments (Summary Of Proceeds, Gross Realized Gains And Gross Realized Losses On Sales Of Available For Sale Securities) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule of Available-for-sale Securities [Line Items]
Proceeds	$ 247,649	$ 147,288	$ 134,276
Gross Realized Gains	35
Gross Realized Losses		$ 5	$ 122

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Equity Method Investments (Reconciliation Of Net Income To Equity In Income) (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Schedule of Variable Interest Entities for Loans to Commercial Borrowers [Line Items]
Equity income based on stated ownership percentages									$ 66,064	$ 81,971	$ 77,882
All other adjustments due to amortization of basis differences, timing of GAAP adjustments and other adjustments									645	(3,316)	(3,800)
Equity in income of investees	$ 18,119	$ 14,546	$ 16,687	$ 17,357	$ 22,131	$ 22,782	$ 18,381	$ 15,361	$ 66,709	$ 78,655	$ 74,082

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Stock-Based Compensation - Summarized Activity of Stock Options (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding at end of period, Weighted-Average Remaining Contractual Term	5 years 2 months 12 days
Exercisable at end of period, Weighted-Average Remaining Contractual Term	4 years 1 month 6 days
Outstanding at beginning of period, Aggregate Intrinsic Value
Outstanding at end of period, Aggregate Intrinsic Value	4,200,000
Exercisable at end of period, Aggregate Intrinsic Value	$ 3,500,000
Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding at beginning of period, Weighted-Average Exercise Price	$ 22.68
Granted, Weighted-Average Exercise Price	$ 25.96
Exercised, Weighted-Average Exercise Price	$ 11.24
Cancelled/expired/forfeited, Weighted-Average Exercise Price	$ 29.05
Outstanding at end of period, Weighted-Average Exercise Price	$ 25.65
Exercisable at end of period, Weighted-Average Exercise Price	$ 22.31
Outstanding at beginning of period, Number of Shares	1,154,000
Granted, Number of Shares	711,000
Exercised, Number of Shares	(262,000)
Cancelled/expired/forfeited, Number of Shares	(171,000)
Outstanding at end of period, Number of Shares	1,432,000
Exercisable at end of period, Number of Shares	536,000

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Long-Term Debt And Notes Payable (Tables)

12 Months Ended

Dec. 31, 2012

Components Of Long-Term Debt And Notes Payable

	December 31,
	2012			2011
	(In thousands)
Long-term debt consists of:
Secured Debt:
Power Generation – various notes payable	$	639		$	831
Other		5			7
		644			838
Less: Amounts due within one year		214			205
Long-term debt	$	430		$	633
Notes payable and current maturities of long-term debt consist of:
Short-term lines of credit	$	3,848		$	4,448
Current maturities of long-term debt		214			205
Total	$	4,062		$	4,653
Interest rate on short-term borrowing		6.6	%		7.2	%

Comparison Of Key Financial Covenants And Current Compliance

A comparison of the key financial covenants and current compliance at December 31, 2012 is as follows:

	Required	Actual
Maximum leverage ratio	Less than 2.75 to 1.0		0.06 to 1.0
Minimum interest coverage ratio	Greater than 4.0 to1.0		78.13 to 1.0

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Basis of Presentation and Significant Accounting Policies (Inventories) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Inventories [Line Items]
Raw Materials and Supplies	$ 98,428	$ 77,932
Work in Progress	7,956	6,889
Finished Goods	17,834	22,477
Total Inventories	$ 124,218	$ 107,298

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Financial Instruments With Concentrations Of Credit Risk

12 Months Ended

Dec. 31, 2012

Financial Instruments With Concentrations Of Credit Risk

NOTE 13 – FINANCIAL INSTRUMENTS WITH CONCENTRATIONS OF CREDIT RISK

Our Power Generation and Nuclear Energy segments’ major customers are large utilities. The primary customer of our Nuclear Operations segment is the U.S. Government, including some of its contractors. These concentrations of customers may impact our overall exposure to credit risk, either positively or negatively, in that our customers may be similarly affected by changes in economic or other conditions. In the years ended December 31, 2012 and 2011, the U.S. Government accounted for approximately 34% and 38%, respectively, of our total revenues. See Note 17 for additional information about our operations in different geographic areas.

We believe that our provision for possible losses on uncollectible accounts receivable is adequate for our credit loss exposure. At December 31, 2012 and 2011, the allowance for possible losses that we deducted from accounts receivable – trade on the accompanying consolidated balance sheets was $3.8 million and $3.3 million, respectively.

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Segment Reporting (Narrative) (Detail) (Customer Concentration Risk [Member])	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Customer Concentration Risk [Member]
Segment Reporting Information [Line Items]
Percentage of revenue from U.S. Government	34.00%	38.00%	39.00%

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Quarterly Financial Data

12 Months Ended

Dec. 31, 2012

Quarterly Financial Data

NOTE 18 – QUARTERLY FINANCIAL DATA (UNAUDITED)

The following tables set forth selected unaudited quarterly financial information for the years ended December 31, 2012 and 2011:

	Year Ended December 31, 2012 Quarter Ended
	March  31, 2012		June  30, 2012		Sept. 30, 2012		Dec. 31, 2012
	(In thousands, except per share amounts)
Revenues	$	765,892	$	852,585	$	807,586	$	865,296
Operating income (1)	$	86,420	$	110,077	$	84,399	$	65,693
Equity in income of investees	$	17,357	$	16,687	$	14,546	$	18,119
Net income attributable to The Babcock & Wilcox Company	$	59,950	$	77,231	$	51,443	$	39,071
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	0.51	$	0.65	$	0.43	$	0.33
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	0.50	$	0.65	$	0.43	$	0.33
(1)       Includes equity in income of investees.

	Year Ended December 31, 2011 Quarter Ended
	March  31, 2011		June  30, 2011		Sept. 30, 2011		Dec. 31, 2011
	(In thousands, except per share amounts)
Revenues	$	691,277	$	752,352	$	707,622	$	800,789
Operating income (loss) (1)	$	41,394	$	82,809	$	74,912	$	(103,444	)
Equity in income of investees	$	15,361	$	18,381	$	22,782	$	22,131
Net income (loss) attributable to The Babcock & Wilcox Company	$	25,921	$	58,665	$	56,742	$	(63,009	)
Earnings per common share:
Basic:
Net income (loss) attributable to The Babcock & Wilcox Company	$	0.22	$	0.50	$	0.48	$	(0.53	)
Diluted:
Net income (loss) attributable to The Babcock & Wilcox Company	$	0.22	$	0.50	$	0.48	$	(0.53	)
(1)       Includes equity in income of investees.

Our March 31, 2011 quarter included additional costs to complete projects totaling $32.7 million. Our June 30, 2011 quarter included $10.9 million of favorable settlements with the sellers of NFS. In addition, our June 30, 2011 and September 30, 2011 quarters included additional costs to complete projects totaling $26.0 million and $3.1 million respectively. Our June 30, 2012 quarter included an $18.1 million favorable settlement with Energy Northwest. Our September 30, 2012 quarter included a $27.0 million impairment of our investment in USEC, Inc. with no related tax benefit and a $25.3 million reduction in our provision for income taxes related to the recognition of previously unrecognized tax benefits.

We have retrospectively applied the new accounting method for recognizing actuarial gains and losses, as described in Note 1. The impact of these adjustments on previously reported quarterly results is summarized below (in thousands, except per share amounts):

Increase (Decrease) from	First Quarter				Second Quarter				Third Quarter				Fourth Quarter
Previously Reported Amounts	2012		2011		2012		2011		2012		2011		2012			2011
Operating income	$	20,709	$	19,493	$	20,718	$	19,552	$	17,092	$	17,361	$	(12,486	)	$	(196,703	)
Net income attributable to The Babcock & Wilcox Company	$	13,206	$	12,411	$	13,207	$	12,456	$	10,922	$	11,079	$	(8,692	)	$	(127,281	)
Earnings per common share:
Basic:
Net income attributable to The Babcock & Wilcox Company	$	0.11	$	0.10	$	0.11	$	0.11	$	0.09	$	0.09	$	(0.07	)	$	(1.07	)
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	0.11	$	0.11	$	0.11	$	0.11	$	0.09	$	0.09	$	(0.07	)	$	(1.07	)

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Stock-Based Compensation - Schedule of Nonvested Cash Settled Performance Units (Detail) (Cash Settled Performance Shares [Member], USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2012
Cash Settled Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Nonvested at beginning of period, Number of Shares
Granted, Number of Units	40
Vested, Number of Units
Cancelled/forfeited, Number of Units	(10)
Nonvested at end of period, Number of Shares	30
Nonvested at end of period, Weighted-Average Fair Value	$ 26.20

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Basis of Presentation and Significant Accounting Policies (Changes in Carrying Amount of Accrued Warranty Expense) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Product Warranty [Line Items]
Balance at beginning of period	$ 97,209	$ 109,588	$ 115,055
Additions	20,972	21,267	31,660
Expirations and other changes	(24,766)	(14,288)	(28,032)
Charges	(10,217)	(19,035)	(10,532)
Translation and other	484	(323)	1,437
Balance at end of period	$ 83,682	$ 97,209	$ 109,588

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Derivative Financial Instruments (Schedule Of Effect Of Derivative Instruments On Statements Of Financial Performance) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
Derivatives Designated As Hedges [Member] | Cash Flow Hedges [Member] | Foreign Exchange Contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in other comprehensive income	$ 2,031	$ (1,224)
Derivatives Designated As Hedges [Member] | Cash Flow Hedges [Member] | Foreign Exchange Contracts [Member] | Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Income (loss) reclassified from accumulated other comprehensive loss into income: effective portion	(1,082)	4,128
Derivatives Designated As Hedges [Member] | Cash Flow Hedges [Member] | Foreign Exchange Contracts [Member] | Cost of Operations [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Income (loss) reclassified from accumulated other comprehensive loss into income: effective portion	3,833	(2,350)
Derivatives Designated As Hedges [Member] | Cash Flow Hedges [Member] | Foreign Exchange Contracts [Member] | Other Expense - Net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Income (loss) reclassified from accumulated other comprehensive loss into income: effective portion	(24)	373
Gain (loss) recognized in income: portion excluded from effectiveness testing	(185)	1,045
Derivatives Not Designated as Hedges [Member] | Foreign Exchange Contracts [Member] | Other Expense - Net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in other comprehensive income
Gain (loss) recognized in income	(169)	1,234
Derivatives Not Designated as Hedges [Member] | Stock Warrants [Member] | Other Expense - Net [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of gain (loss) recognized in other comprehensive income
Gain (loss) recognized in income	$ (560)	$ (2,419)

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Segment Reporting (Tables)

12 Months Ended

Dec. 31, 2012

Schedule Of Revenues By Segment

1. Information about Operations in our Different Industry Segments:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
REVENUES (1):
Power Generation	$	1,785,959		$	1,541,509		$	1,424,574
Nuclear Operations		1,098,031			1,043,185			995,969
Technical Services		107,851			119,711			90,147
Nuclear Energy		325,953			321,406			196,282
Adjustments and Eliminations		(26,435	)		(73,771	)		(18,161	)
	$	3,291,359		$	2,952,040		$	2,688,811

⁽¹⁾  Segment revenues are net of the following intersegment transfers and other adjustments:

Power Generation Transfers	$	7,932	$	53,852	$	5,092
Nuclear Operations Transfers		6,015		5,860		4,423
Technical Services Transfers		3,496		2,155		2,438
Nuclear Energy Transfers		8,992		11,904		6,208
	$	26,435	$	73,771	$	18,161

Schedule Of Revenue By Segment, Intersegment Information

Power Generation Transfers	$	7,932	$	53,852	$	5,092
Nuclear Operations Transfers		6,015		5,860		4,423
Technical Services Transfers		3,496		2,155		2,438
Nuclear Energy Transfers		8,992		11,904		6,208
	$	26,435	$	73,771	$	18,161

Schedule Of Operating Income By Segment

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
OPERATING INCOME:
Power Generation	$	183,387		$	183,984		$	169,113
Nuclear Operations		226,269			194,438			168,636
Technical Services		59,655			69,915			47,122
Nuclear Energy		(62,879	)		(116,887	)		(26,442	)
	$	406,432		$	331,450		$	358,429
Unallocated Corporate(1)		(27,953	)		(20,361	)		(18,029	)
Mark to Market Adjustment		(31,890	)		(215,418	)		(91,545	)
Total Operating Income(2)	$	346,589		$	95,671		$	248,855
Other Income (Expense):
Interest income		1,491			1,342			1,187
Interest expense		(3,735	)		(4,543	)		(12,938	)
Other income (expense)—net		(24,927	)		2,028			(16,896	)
Total Other Expense		(27,171	)		(1,173	)		(28,647	)
Income before Provision for Income Taxes	$	319,418		$	94,498		$	220,208

⁽¹⁾       Unallocated corporate includes general corporate overhead not allocated to segments

⁽²⁾       Included in operating income is the following:

(Gains) Losses on Asset Disposals – Net:
Power Generation	$	3,276		$	(3,456	)	$	39
Nuclear Operations		(339	)		—			—
Technical Services		(1,517	)		—			61
Nuclear Energy		(1	)		96			(62	)
Unallocated Corporate		—			273			—
	$	1,419		$	(3,087	)	$	38
Equity in Income of Investees:
Power Generation	$	17,402		$	25,778		$	30,788
Nuclear Operations		—			—			—
Technical Services		49,621			52,877			43,294
Nuclear Energy		(314	)		—			—
	$	66,709		$	78,655		$	74,082

Schedule Of Operating Income By Segment, Additional Information

(Gains) Losses on Asset Disposals – Net:
Power Generation	$	3,276		$	(3,456	)	$	39
Nuclear Operations		(339	)		—			—
Technical Services		(1,517	)		—			61
Nuclear Energy		(1	)		96			(62	)
Unallocated Corporate		—			273			—
	$	1,419		$	(3,087	)	$	38
Equity in Income of Investees:
Power Generation	$	17,402		$	25,778		$	30,788
Nuclear Operations		—			—			—
Technical Services		49,621			52,877			43,294
Nuclear Energy		(314	)		—			—
	$	66,709		$	78,655		$	74,082

Schedule Of Segment Reporting Information

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
SEGMENT ASSETS:
Power Generation	$	1,059,824	$	1,325,959	$	1,082,801
Nuclear Operations		708,607		679,818		639,090
Technical Services		125,494		123,717		85,509
Nuclear Energy		401,233		347,158		339,457
Total Segment Assets		2,295,158		2,476,652		2,146,857
Corporate Assets		545,197		312,459		353,653
Total Assets	$	2,840,355	$	2,789,111	$	2,500,510
CAPITAL EXPENDITURES:
Power Generation	$	24,592	$	15,788	$	13,627
Nuclear Operations		44,810		32,082		24,718
Technical Services		—		—		15
Nuclear Energy		8,435		7,257		4,480
Segment Capital Expenditures		77,837		55,127		42,840
Corporate Capital Expenditures		8,798		8,747		20,809
Total Capital Expenditures	$	86,635	$	63,874	$	63,649
DEPRECIATION AND AMORTIZATION:
Power Generation	$	19,126	$	17,264	$	18,564
Nuclear Operations		32,013		38,169		36,955
Technical Services		244		262		263
Nuclear Energy		6,202		5,346		4,988
Segment Depreciation and Amortization		57,585		61,041		60,770
Corporate Depreciation and Amortization		12,112		11,962		10,863
Total Depreciation and Amortization	$	69,697	$	73,003	$	71,633
INVESTMENT IN UNCONSOLIDATED AFFILIATES:
Power Generation	$	139,399	$	124,686	$	95,527
Nuclear Operations		—		—		—
Technical Services		46,928		38,882		5,284
Nuclear Energy		27		—		—
Total Investment in Unconsolidated Affiliates	$	186,354	$	163,568	$	100,811

Schedule Of Revenue Information From Products And Service Lines

2. Information about our Product and Service Lines:

	Year Ended December 31,
	2012			2011			2010
	(In thousands)
REVENUES:
Power Generation:
New Build Environmental Equipment	$	446,514		$	235,750		$	277,531
New Build Steam Generation Systems		511,201			416,779			386,356
Aftermarket Services		841,571			894,677			765,573
Eliminations/Other		(13,327	)		(5,697	)		(4,886	)
		1,785,959			1,541,509			1,424,574
Nuclear Operations:
Nuclear Component Program		1,086,081			1,025,838			986,952
Commercial Operations		5,908			11,674			4,449
Eliminations/Other		6,042			5,673			4,568
		1,098,031			1,043,185			995,969
Technical Services:
Commercial Operations		20,819			29,708			28,862
Nuclear Environmental Services		78,228			76,267			48,351
Management & Operation Contracts of U.S. Government Facilities		8,804			13,736			12,934
Eliminations/Other		—			—			—
		107,851			119,711			90,147
Nuclear Energy:
Nuclear Services		158,365			151,118			119,244
Nuclear Equipment		134,011			122,789			72,336
Nuclear Projects		33,319			45,539			4,700
Eliminations/Other		258			1,960			2
		325,953			321,406			196,282
Eliminations		(26,435	)		(73,771	)		(18,161	)
	$	3,291,359		$	2,952,040		$	2,688,811

Schedule Of Revenues By Geographical Area

3. Information about our Operations in Different Geographic Areas:

	Year Ended December 31,
	2012		2011		2010
	(In thousands)
REVENUES(1):
United States	$	2,615,387	$	2,340,299	$	2,133,924
Canada		288,246		238,663		252,089
Sweden		101,688		94,337		48,632
China		45,830		48,153		48,285
Germany		34,364		8,222		3,464
Argentina		23,529		21,016		4,374
Denmark		18,504		12,310		15,040
Finland		17,143		20,723		4,040
Korea		14,461		6,272		9,114
India		13,306		8,891		16,277
Chile		11,582		6,811		2,870
Norway		9,939		29,844		33,353
Italy		8,477		6,516		11,361
Saudi Arabia		7,973		3,307		1,689
Indonesia		7,828		4,642		6,048
United Kingdom		6,653		6,150		6,791
Japan		6,497		8,716		8,797
Bulgaria		2,620		14,149		2,144
Brazil		2,585		4,671		2,957
France		2,384		3,433		5,373
Ireland		2,189		14,769		26,574
Other Countries		50,174		50,146		45,615
	$	3,291,359	$	2,952,040	$	2,688,811
(1)       We allocate geographic revenues based on the location of the customer’s operations.
NET PROPERTY, PLANT AND EQUIPMENT:
United States	$	363,447	$	348,498	$	345,848
Canada		45,402		41,868		41,959
United Kingdom		9,714		9,758		10,401
Denmark		8,565		8,813		8,395
Mexico		8,302		7,024		6,299
Other Countries		11,591		6,330		5,410
	$	447,021	$	422,291	$	418,312

Schedule Of Property, Plant And Equipment, Net By Geographical Area

NET PROPERTY, PLANT AND EQUIPMENT:
United States	$	363,447	$	348,498	$	345,848
Canada		45,402		41,868		41,959
United Kingdom		9,714		9,758		10,401
Denmark		8,565		8,813		8,395
Mexico		8,302		7,024		6,299
Other Countries		11,591		6,330		5,410
	$	447,021	$	422,291	$	418,312

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Fair Values Of Financial Instruments (Summary Of Available-For-Sale Securities Measured At Fair Value) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	$ 92,859	$ 72,580
Mutual Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	3,637	3,312
U.S. Government And Agency Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	21,446	51,322
Asset-backed securities and collateralized mortgage obligations [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	454	462
Commercial Paper [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	67,322	17,484
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	21,446	51,322
Level 1 [Member] | U.S. Government And Agency Securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	21,446	51,322
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	71,413	21,258
Level 2 [Member] | Mutual Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	3,637	3,312
Level 2 [Member] | Asset-backed securities and collateralized mortgage obligations [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	454	462
Level 2 [Member] | Commercial Paper [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available-for-sale securities measured at fair value	$ 67,322	$ 17,484

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Consolidated And Combined Statements Of Comprehensive Income (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Net income	$ 217,557	$ 70,618	$ 140,203
Other Comprehensive Income (Loss):
Foreign currency translation adjustments	4,284	747	7,561
Unrealized gains (losses) on derivative financial instruments:
Unrealized gains (losses) on derivative financial instruments	1,409	(877)	6,407
Reclassification adjustment for gains (losses) included in net income	(2,023)	1,655	1,290
Unrecognized losses on benefit obligations:
Unrecognized losses arising during the period	(434)	(1,205)	(551)
Amortization of losses included in net income	2,281	2,487	2,386
Unrealized gains (losses) on investments:
Unrealized gains (losses) arising during the period	431	(74)	523
Reclassification adjustment for net (losses) gains included in net income	(35)	5	122
Other Comprehensive Income	5,913	2,738	17,738
Total Comprehensive Income	223,470	73,356	157,941
Comprehensive Loss (Income) Attributable to Noncontrolling Interest	10,127	7,670	(243)
Comprehensive Income Attributable to The Babcock & Wilcox Company	$ 233,597	$ 81,026	$ 157,698

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Asset Sales And Impairment Of Long-Lived Assets (Narrative) (Detail) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
(Gains) losses on asset disposals and impairments - net	$ 1,419	$ (3,087)	$ 38

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Business Acquisitions And Investments

12 Months Ended

Dec. 31, 2012

Business Acquisitions And Investments

NOTE 2 – BUSINESS ACQUISITIONS AND INVESTMENTS

Anlagenbau und Fördertechnik Arthur Loibl GmbH

In November 2011, our Power Generation segment, acquired Anlagenbau und Fördertechnik Arthur Loibl GmbH (“Loibl”) for approximately $24.2 million. The acquisition of Loibl, a German-based manufacturer of material handling equipment, will expand the products, services and global reach of our Power Generation segment’s ash handling business, which is one of the world’s leading suppliers of ash handling solutions for the power generation and other industries.

In connection with the Loibl acquisition, we recorded goodwill of approximately $14.7 million, intangible assets of $7.6 million, property, plant and equipment of $2.5 million and other net liabilities totaling $0.9 million. During 2012, we finalized our purchase price allocation for the Loibl acquisition, resulting in an increase to goodwill of approximately $3.7 million. The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Customer relationships	$	3,200	8 years
Backlog	$	3,100	2 years
Tradename	$	800	5 years
Unpatented technology	$	500	12 years

GE Energy Businesses

On April 2, 2010, we acquired the assets of the electrostatic precipitator aftermarket and emissions monitoring business units of GE Energy, a division of General Electric Company, for approximately $21.4 million. This acquisition includes GE Energy’s electrostatic precipitator replacement parts and mechanical components product lines, performance-enhancing hardware, controls and software, remote diagnostics equipment and emissions monitoring products and services. These products and services are used by a wide variety of power generation and industrial customers to monitor and control particulates and other emissions from power plants, factories and other facilities. These business units maintain offices in the United States in Kansas City, Missouri; Folkston, Georgia; Newport News, Virginia and Hatfield, Pennsylvania, as well as locations in Germany and China.

In connection with the GE acquisition, we recorded goodwill of $4.8 million, property, plant and equipment of $4.0 million, intangible assets of $5.5 million, and other net assets totaling $7.1 million. The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Customer relationships	$	3,700	10 years
Patented technology	$	1,000	10 years
Backlog	$	400	1.5 years
Tradename	$	400	10 years

Götaverken Miljö AB

In January 2010, we acquired the net assets of Gőtaverken Miljő AB, a flue gas cleaning and energy recovery company based in Gothenburg, Sweden for approximately $8.6 million. In connection with this acquisition, we recorded goodwill of $3.2 million, intangible assets of $6.4 million, and other net liabilities totaling $1.0 million The intangible assets consist of the following (dollar amounts in thousands):

	Amount		Amortization Period
Patented technology	$	2,460	15 years
Customer relationships	$	2,120	12 years
Tradenames and trademarks	$	1,160	20 years
Backlog	$	610	0.5 years

None of these acquisitions, either individually or in the aggregate, were considered significant. The proforma effect of these acquisitions are not material to our results of operations.

USEC, Inc. Investment

In May 2010, our subsidiary Babcock & Wilcox Investment Company (“BWICO”) entered into an agreement with Toshiba Corporation (“Toshiba”), which was subsequently assigned to one of its subsidiaries, and USEC Inc. (“USEC”) to make a strategic investment in USEC totaling $200 million payable over three phases. In September 2010, following the satisfaction of certain conditions, including the availability to USEC’s American Centrifuge program of at least $2 billion in uncommitted funds under the DOE’s loan guarantee program for front-end nuclear fuel facilities and the establishment of a joint venture between us and USEC for supply by the joint venture of centrifuges and related equipment for the American Centrifuge program, we made a $37.5 million investment in USEC as part of a definitive agreement for us to make a total $100 million strategic investment in USEC.

In connection with our investment, we received 37,500 shares of USEC Series B-1 12.75% Convertible Preferred Stock and Warrants to purchase 3,125,000 shares of USEC Class B Common Stock at an exercise price of $7.50 per share, which are exercisable between January 1, 2015 and December 31, 2016, and a seat on USEC’s board of directors.

In 2011, we entered into a standstill agreement with USEC and Toshiba when it became apparent that USEC would not be able to satisfy the closing conditions applicable to the second phase of the strategic investment. Pursuant to the standstill agreement, each party agreed not to exercise its right to terminate the strategic investment agreement for a limited standstill period, as subsequently extended. USEC has been unable to satisfy the closing conditions to the second and third phases of the strategic investment and the limited standstill period, as extended, has expired. Currently, BWICO, Toshiba and USEC each have the right to terminate their obligations under the original strategic investment agreement.

On June 12, 2012, USEC entered into a Cooperative Agreement with the DOE to provide funding for a cost-share research, development and demonstration (“RD&D”) program to enhance the technical and financial readiness of centrifuge technology for commercialization. The Cooperative Agreement provides for 80% DOE and 20% USEC cost sharing for work performed during the period from June 1, 2012 through December 31, 2013, with a total estimated cost of $350 million. The Cooperative Agreement will be incrementally funded and DOE funding was initially limited to $87.7 million until the DOE provides authorization for additional funding. Execution of the Cooperative Agreement satisfies the requirement of USEC’s credit facility that USEC shall have entered into a definitive agreement with the DOE for the RD&D program in order to continue spending on the American Centrifuge program. Under the credit facility, USEC can invest its 20% share of the costs under the RD&D program as long as the amount of the expenditures reimbursable to USEC under the RD&D program that have not yet been reimbursed does not exceed $50 million.

On August 1, 2012 USEC filed its quarterly report for the period ended June 30, 2012 on Form 10-Q with the Securities and Exchange Commission. This report contained several updated risk factors (along with other disclosures) concerning operational and structural issues facing USEC including, but not limited to, the future operations of USEC’s Paducah Gaseous Diffusion Plant, achievement of milestones under the RD&D program discussed above, approved funding for the RD&D program, achievement of milestones under a 2002 DOE-USEC Agreement to develop, demonstrate and deploy the American Centrifuge technology and possible failure to maintain compliance with listing requirements of the New York Stock Exchange which could result in a delisting of USEC’s common stock (which could require USEC to repurchase its convertible notes for cash and trigger a default under its credit facility). In addition, on August 15, 2012 Standard and Poor’s lowered its ratings on USEC, including the corporate credit rating to CCC from CCC+ along with a negative outlook. Standard and Poor’s also lowered its issue-level rating on USEC’s senior convertible notes due October 2014 to CC from CCC-. We determined, based on the facts and circumstances disclosed above, that a fair value determination of our cost-method investment in USEC Preferred Stock was warranted. We have established, with the assistance of a third party valuation firm, that the fair value of our investment in USEC Preferred Stock totals $19.1 million. Fair value was determined using a combination of an option pricing model and a probability of default methodology. We believe the gross unrealized loss on our USEC Preferred Stock investment is other than temporarily impaired, and as a result we have included in other income (expense)—net on our consolidated and combined statements of income an impairment charge totaling $27.0 million related to our investment in USEC Preferred Stock to write our investment down to its estimated fair value. We continue to support the American Centrifuge program through the ongoing manufacturing of components and technical support of the development program, and are presently exploring various restructuring alternatives with USEC and will continue to monitor these developments and evaluate our remaining investment in USEC Preferred Stock as new facts become available.

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Business Acquisitions And Investments (Narrative) (Detail) (USD $)	1 Months Ended		12 Months Ended			1 Months Ended		3 Months Ended	12 Months Ended			1 Months Ended								12 Months Ended				1 Months Ended
	Aug. 31, 2012	Apr. 02, 2010	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Jun. 30, 2012 USEC, Inc. Investment [Member]	Sep. 30, 2010 USEC, Inc. Investment [Member]	Sep. 30, 2012 USEC, Inc. Investment [Member]	Dec. 31, 2012 USEC, Inc. Investment [Member]	Aug. 31, 2012 USEC, Inc. Investment [Member]	Jun. 12, 2012 USEC, Inc. Investment [Member]	May 31, 2010 USEC, Inc. Investment [Member] Toshiba Corporation [Member]	May 31, 2010 USEC, Inc. Investment [Member] Series B-1 [Member]	May 31, 2010 USEC, Inc. Investment [Member] Common Class B [Member]	May 31, 2010 USEC, Inc. Investment [Member] Common Class B [Member] Minimum [Member]	May 31, 2010 USEC, Inc. Investment [Member] Common Class B [Member] Maximum [Member]	Sep. 30, 2010 USEC, Inc. Investment [Member] Front-End Nuclear Fuel Facilities [Member]	Sep. 30, 2010 USEC, Inc. Investment [Member] American Centrifuge Project [Member]	Jun. 30, 2012 US Department Of Energy (DOE) [Member]	Dec. 31, 2012 US Department Of Energy (DOE) [Member]	Dec. 31, 2012 Anlagenbau und Fordertechnik Arthur Loibl GmbH [Member]	Nov. 30, 2011 Anlagenbau und Fordertechnik Arthur Loibl GmbH [Member]	Apr. 02, 2010 Ge Energy Businesses [Member]	Jan. 31, 2010 Gotaverken Miljo AB [Member]
Business Acquisitions And Investments [Line Items]
Acquisition purchase price																						$ 24,200,000	$ 21,400,000	$ 8,600,000
Goodwill																						14,700,000	4,800,000	3,200,000
Intangible assets acquired																						7,600,000	5,500,000	6,400,000
Property, plant and equipment																						2,500,000	4,000,000
Other net liabilities																						900,000		1,000,000
Loibl acquisition, increase in goodwill																					3,700,000
Business acquisition date		April 2, 2010																						January 2010
Other net assets																							7,100,000
Strategic investment business agreement date												May 2010
Strategic investment			6,064,000	38,176,000	42,912,000		100,000,000					200,000,000						37,500,000
Uncommitted funds																	2,000,000,000
Number of convertible preferred stock received													37,500
Percentage of convertible preferred stock													12.75%
Number of warrants to purchase common stock														3,125,000
Common stock exercise price per share														$ 7.50
Warrants exercisable date															Jan. 01, 2015	Dec. 31, 2016
Cooperative agreement percents						20.00%			20.00%											80.00%
Estimated cost											350,000,000
Initial funding																			87,700,000
Cooperative agreement funding reimbursement						50,000,000
Fair value of our investment			19,100,000							19,100,000
Impairment charge totaling	$ 27,000,000		$ 27,000,000					$ 27,000,000

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Pension Plans And Postretirement Benefits (Plan Asset Allocations By Asset Category) (Detail)	Dec. 31, 2012	Dec. 31, 2011
Domestic Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	100.00%	100.00%
Domestic Plans [Member] | Commingled And Mutual Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	34.00%	25.00%
Domestic Plans [Member] | Fixed Income (Excluding U. S. Government Securities) [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	29.00%	27.00%
Domestic Plans [Member] | U.S. Government Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	22.00%	18.00%
Domestic Plans [Member] | Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	6.00%	17.00%
Domestic Plans [Member] | Partnerships With Security Holdings [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	6.00%	8.00%
Domestic Plans [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	1.00%	3.00%
Domestic Plans [Member] | Other [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	2.00%	2.00%
Foreign Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	100.00%	100.00%
Foreign Plans [Member] | Other [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	2.00%	3.00%
Foreign Plans [Member] | Equity Securities And Commingled Mutual Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	58.00%	56.00%
Foreign Plans [Member] | Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	40.00%	41.00%

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Fair Values Of Financial Instruments (Narrative) (Detail) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Fair Values Of Financial Instruments [Line Items]
Net unrealized (gain) losses on investments	$ 600,000	$ 200,000
Notional amount of foreign currency forward contracts	170,300,000
Fair value of foreign currency forward contracts	3,300,000
Percentage Of Stock Price Discount For Inactive Shares	40.00%
Fair value of warrants	317,000	877,000	3,296,000
Fair value of our investment	19,100,000
Minimum [Member]
Fair Values Of Financial Instruments [Line Items]
Estimated default recovery rates	30.00%
Maximum [Member]
Fair Values Of Financial Instruments [Line Items]
Estimated default recovery rates	50.00%
Stock Warrants [Member]
Fair Values Of Financial Instruments [Line Items]
Fair value of warrants	$ 300,000

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Income Taxes (Components Of Provision For Income Taxes) (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Provision For Income Taxes [Line Items]
U.S. - federal		$ 39,784	$ 24,591	$ 29,191
U.S. - state and local		7,979	7,452	8,029
Other than U.S.		11,060	11,037	11,617
Total current		58,823	43,080	48,837
U.S. - Federal		24,560	(20,066)	33,541
U.S. - State and local		6,545	5,195	(389)
Other than U.S.		11,933	(4,329)	(1,984)
Total deferred (benefit) provision		43,038	(19,200)	31,168
Provision for income taxes	$ 0	$ 101,861	$ 23,880	$ 80,005

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Earnings Per Share

12 Months Ended

Dec. 31, 2012

Earnings Per Share

NOTE 19 – EARNINGS PER SHARE

The following table sets forth the computation of basic and diluted earnings per share:

	Year Ended December 31,
	2012		2011		2010
	(In thousands, except shares and per share amounts)
Basic:
Net income attributable to The Babcock & Wilcox Company	$	227,695	$	78,319	$	139,939
Weighted average common shares		118,418,930		117,560,594		116,260,425
Basic earnings per common share:
Net income attributable to The Babcock & Wilcox Company	$	1.92	$	0.67	$	1.20
Diluted:
Net income attributable to The Babcock & Wilcox Company	$	227,695	$	78,319	$	139,939
Weighted average common shares (basic)		118,418,930		117,560,594		116,260,425
Effect of dilutive securities:
Stock options, restricted stock and performance shares(1)		602,394		844,003		1,365,640
Adjusted weighted average common shares		119,021,324		118,404,597		117,626,065
Diluted earnings per common share:
Net income attributable to The Babcock & Wilcox Company	$	1.91	$	0.66	$	1.19

(1) At December 31, 2012, 2011 and 2010, we excluded from the diluted share calculation 1,082,904, 742,035 and 349,744 shares, respectively, related to stock options, as their effect would have been antidilutive.

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Quarterly Financial Data - (Narrative) (Detail) (USD $)	1 Months Ended	3 Months Ended					12 Months Ended			3 Months Ended
	Aug. 31, 2012	Dec. 31, 2012	Jun. 30, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Sep. 30, 2012 USEC, Inc. Investment [Member]
Quarterly Financial Data [Line Items]
Project costs						$ 32,700,000
Additional project costs				3,100,000	26,000,000		16,900,000	61,800,000
Gain on settlement with sellers of NFS			18,100,000		10,900,000
Impairment of Investment in USEC, Inc	27,000,000						27,000,000			27,000,000
Related Tax Benefit (Income Tax)		0					101,861,000	23,880,000	80,005,000
Reduction of Provision for Income Taxes Related to Previous Unrecognized Tax Benefits		$ 25,300,000					$ 24,700,000	$ 3,023,000

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Long-Term Debt And Notes Payable (Comparison Of Key Financial Covenants And Current Compliance) (Detail)	12 Months Ended
	Dec. 31, 2012
Required [Member]
Debt Instrument [Line Items]
Maximum leverage ratio	2.75
Minimum interest coverage ratio	4.00
Actual [Member]
Debt Instrument [Line Items]
Maximum leverage ratio	0.06
Minimum interest coverage ratio	78.13

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Investments (Tables)

12 Months Ended

Dec. 31, 2012

Summary Of Available-For-Sale Securities

The following is a summary of our available-for-sale securities at December 31, 2012:

	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Estimated Fair  Value
	(In thousands)
U.S. Government and agency securities	$	21,436	$	10	$	—		$	21,446
Mutual funds		2,958		679		—			3,637
Asset-backed securities and collateralized mortgage obligations		554		2		(102	)		454
Commercial paper		67,313		9		—			67,322
Total	$	92,261	$	700	$	(102	)	$	92,859

The following is a summary of our available-for-sale securities at December 31, 2011:

	Amortized Cost		Gross Unrealized Gains		Gross Unrealized Losses			Estimated Fair  Value
	(In thousands)
U.S. Government and agency securities	$	51,308	$	14	$	—		$	51,322
Mutual funds		2,957		355		—			3,312
Asset-backed securities and collateralized mortgage obligations		633		—		(171	)		462
Commercial paper		17,481		4		(1	)		17,484
Total	$	72,379	$	373	$	(172	)	$	72,580

Summary Of Proceeds, Gross Realized Gains And Gross Realized Losses On Sales Of Available-For-Sale Securities

Proceeds, gross realized gains and gross realized losses on sales of available-for-sale securities were as follows:

	Proceeds		Gross Realized  Gains		Gross Realized  Losses
	(In thousands)
Year Ended December 31, 2012	$	247,649	$	35	$	—
Year Ended December 31, 2011	$	147,288	$	—	$	5
Year Ended December 31, 2010	$	134,276	$	—	$	122

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Risks And Uncertainties

12 Months Ended

Dec. 31, 2012

Risks And Uncertainties

NOTE 12 – RISKS AND UNCERTAINTIES

Percentage-of-Completion Accounting

As of December 31, 2012, in accordance with the percentage-of-completion method of accounting, we have provided for our estimated costs to complete all of our ongoing contracts. However, it is possible that current estimates could change due to unforeseen events, which could result in adjustments to overall contract costs. The risk on fixed-priced contracts is that revenue from the customer does not cover increases in our costs. It is possible that current estimates could materially change for various reasons, including, but not limited to, fluctuations in forecasted labor productivity or steel and other raw material prices. Increases in costs on our fixed-price contracts could have a material adverse impact on our consolidated financial condition, results of operations and cash flows. Alternatively, reductions in overall contract costs at completion could materially improve our consolidated financial condition, results of operations and cash flows.

Insurance

Upon the February 22, 2006 effectiveness of the settlement relating to the Chapter 11 proceedings involving several of our subsidiaries, most of our subsidiaries contributed substantial insurance rights to the asbestos personal injury trust, including rights to (1) certain pre-1979 primary and excess insurance coverages and (2) certain of our 1979-1986 excess insurance coverage. These insurance rights provided coverage for, among other things, asbestos and other personal injury claims, subject to the terms and conditions of the policies. The contribution of these insurance rights was made in exchange for the agreement on the part of the representatives of the asbestos claimants, including the representative of future claimants, to the entry of a permanent injunction, pursuant to Section 524(g) of the U.S. Bankruptcy Code, to channel to the asbestos trust all asbestos-related claims against our subsidiaries and former subsidiaries arising out of, resulting from or attributable to their operations, and the implementation of related releases and indemnification provisions protecting those subsidiaries and their affiliates from future liability for such claims. Although we are not aware of any significant, unresolved claims against our subsidiaries and former subsidiaries that are not subject to the channeling injunction and that relate to the periods during which such excess insurance coverage related, with the contribution of these insurance rights to the asbestos personal injury trust, it is possible that we could have underinsured or uninsured exposure for non-derivative asbestos claims or other personal injury or other claims that would have been insured under these coverages had the insurance rights not been contributed to the asbestos personal injury trust.

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Investments (Summary Of Available-For-Sale Securities) (Detail) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost	$ 92,261	$ 72,379
Gross Unrealized Gains	700	373
Gross Unrealized Losses	(102)	(172)
Estimated Fair Value	92,859	72,580
U.S. Treasury securities and obligations of U.S. Government agencies [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost	21,436	51,308
Gross Unrealized Gains	10	14
Estimated Fair Value	21,446	51,322
Mutual Funds [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost	2,958	2,957
Gross Unrealized Gains	679	355
Estimated Fair Value	3,637	3,312
Asset-backed securities and collateralized mortgage obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost	554	633
Gross Unrealized Gains	2
Gross Unrealized Losses	(102)	(171)
Estimated Fair Value	454	462
Commercial paper [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost	67,313	17,481
Gross Unrealized Gains	9	4
Gross Unrealized Losses		(1)
Estimated Fair Value	$ 67,322	$ 17,484